DCL-11-072, LAR-11-006 - Revision to Technical Specification 3.3.5. Loss of Power (LOP) Diesel Generator (DG) Start Instrumentation

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LAR-11-006 - Revision to Technical Specification 3.3.5. Loss of Power (LOP) Diesel Generator (DG) Start Instrumentation
ML113010200
Person / Time
Site: Diablo Canyon  Pacific Gas & Electric icon.png
Issue date: 10/24/2011
From: Becker J R
Pacific Gas & Electric Co
To:
Document Control Desk, Office of Nuclear Reactor Regulation
Shared Package
ML113010196 List:
References
LAR-11-006, PG&E Letter DCL-11-072
Download: ML113010200 (200)
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Text

Pacific Gas and Electric Company O ctober 2 4, 2 011 PG&E Letter DCL-11-072 u.s. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, D.C. 20555-0001 Diablo Canyon Units 1 and 2 Docket No. 50-275, OL-DPR-80 Docket No. 50-323, OL-DPR-82 License Amendment Request 11-06 J ames R. B ecker S i te V i ce Pres i de n t Diablo Canyon Power Plant Mai l C o de 104/5/601 p. O. Box 56 Av il a Beach , CA 93424 805.545.3462 In te rnal: 6 9 1.3462 Fax: 805.545.6445 10 CFR 50.90 Revision to Technical Specification 3.3.5. "Loss of Power (LOP) Diesel Generator (DG) Start Instrumentation"

Reference:

1. PG&E letter DCL-1 0-115, "Licensee Event Report 1-2010-002-02, Potential Loss of Safety-Related Pumps due to Degraded Voltage During Postulated Accidents," dated September 24, 2010. Dear Commissioners and Staff: Pursuant to 10 CFR 50.90, Pacific Gas and Electric Company (PG&E) hereby requests approval of the enclosed proposed amendment to Facility Operating License Nos. DPR-80 and DPR-82 for Units 1 and 2 of the Diablo Canyon Power Plant (DCPP) respectively.

The enclosed license amendment request (LAR) proposes to revise Technical Specification (TS) 3.3.5, "Loss of Power (LOP) Diesel Generator (DG) Start Instrumentation," revise Final Safety Analysis Report Update (FSARU) Appendix 6.2D and Sections 6.3, 15.3, and 15.4, revise the loss-of-coolant accident (LOCA) control room operator and offsite dose analysis of record described in the FSARU, and provide a new process for revising input values to this analysis.

The current TS 3.3.5.3.a Surveillance Requirement (SR) contains loss of voltage Load Shed Allowable Values (A V) that are nonconservative during postulated sustained degraded grid voltage conditions.

The changes proposed in this LAR correct the nonconservative first level undervoltage relays (FLUR) TS limits contained in the current TS SR 3.3.5.3. The DCPP Units 1 and 2 safety analyses of record have been evaluated for engineered safety feature (ESF) component actuation time delay that bounds the maximum second level undervoltage relay (SLUR) time delay, and have been determined to remain within the DCPP licensing basis acceptance criteria. The proposed amendment would revise the FSARU to increase ESF component delay times described in the FSARU accident analyses to bound the current maximum SLUR actuation.

The proposed amendment would revise the analysis of record for the LOCA control room operator and offsite dose calculations described in the FSARU. The proposed amendment revises inputs to A member of the STARS (Strategic Te a ming and Resource Sha ri ng) All i ance Callaway

  • Comanche Peak
  • D i ablo Canyon
  • Palo Verde
  • San Onofre
  • Wolf Creek

_Document Control Desk 24,2011 Page 2 PG&E Letter DCL-11-072 the LOCA control room operator and offsite doses and does not increase the limiting total control room operator or offsite doses. The proposed amendment would provide a new process for revising input values for the LOCA control room operator and offsite dose analysis.

PG&E requests approval of this LAR no later than October 24, 2012. PG&E requests the license amendment(s) be made effective upon NRC issuance, to be implemented during Unit 2 Refueling Outage 17 and Unit 1 Refueling Outage 18. PG&E is making regulatory commitments (as defined by NEI 99-04) in this letter. Attachment 5 of the Enclosure summarizes the regulatory commitments made in this letter. This letter includes no revisions to existing regulatory commitments.

This letter satisfies a commitment in Reference 1, "PG&E will submit a license amendment request to establish conservative TS SR 3.3.5.3 undervoltage relays settings." In accordance with 10 CFR 50.91, PG&E is notifying the State of California of this LAR by transmitting a copy of this letter and enclosures to the designated State Official.

If you have any questions or require additional information, please contact Mr. Tom Baldwin at 805-545-4720.

I state under penalty of perjury that the foregoing is true and correct. Executed on October 24,2011. --Site Vice President d ngd/4955/50353334

Enclosure:

Evaluation of the Proposed Change cc: Diablo Distribution cc/enc: Gary W. Butner, Branch Chief, California Dept of Public Health Elmo E. Collins, NRC Region IV Michael S. Peck, NRC, Senior Resident Inspector James T. Polickoski, NRR Project Manager Alan B. Wang, NRR Project Manager A member of the STARS (Strategic Teami ng and Resource Sharing) Alliance Callaway

  • Comanche Peak
  • Diablo Canyon
  • Palo Verde
  • San Onofre

SUMMARY

DESCRIPTION

2. DETAILED DESCRIPTION
3. TECHNICAL EVALUATION 3.1 SR 3.3.5.3 Design Basis 3.2 Evaluation of Impact of SLUR Time Delay on Accident Analysis 3.3 Evaluation of Impact of SLUR Time Delay on LOCA Dose Analysis 4. REGULATORY EVALUATION 4.1 Applicable Regulatory Requirements/Criteria 4.2 Precedent 4.3 Significant Hazards Consideration 4.4 Conclusions
5. ENVIRONMENTAL CONSIDERATION
6. REFERENCES ATTACHMENTS:
1. Proposed Technical Specification Changes (marked-up)
2. Proposed Technical Specification Changes (retyped)
3. Changes to Technical Specification Bases Pages (For Information Only) 4. FSARU Markups 5. Commitments
6. PG&E Calculation 357S-DC 7. PG&E Calculation STA-195 EVALUATION
1.

SUMMARY

DESCRIPTION Enclosure PG&E Letter DCL-11-072 This letter is a request to amend Operating Licenses DPR-80 and DPR-82 for Units 1 and 2 of the Diablo Canyon Power Plant (DCPP), respectively.

The proposed changes would revise the Operating Licenses to revise the Technical Specification (TS) 3.3.5, "Loss of Power (LOP) Diesel Generator (DG) Start Instrumentation." Additionally, the proposed changes would revise the DCPP Units 1 and 2 safety analyses of record to increase the engineered safety feature (ESF) component actuation time delay such that it bounds the maximum second level undervoltage relay (SLUR) time delay. The proposed amendment would revise the analysis of record for the loss-of-coolant accident (LOCA) control room operator and offsite dose analysis described in the Final Safety Analysis Report Update (FSARU). The proposed amendment revises inputs to the LOCA control room operator and offsite doses and does not increase the total limiting control room operator or offsite doses. The proposed amendment would provide a new process for revising input values for the LOCA control room operator and offsite dose analysis.

The changes proposed in this license amendment request (LAR) correct the nonconservative first level undervoltage relays (FLUR) TS limits contained in the current TS 3.3.5.3 Surveillance Requirement (SR). The proposed amendments would revise the FSARU to increase ESF component delay times used in the FSARU accident analyses to bound the current maximum SLUR actuation time delay. The NRC provided requirements of the second level of voltage protection for the onsite power system in Reference

1. The changes specified in this LAR are being made to comply with the conditions set forth below: "We require that a second level of voltage protection for the onsite power system be provided and that this second level of voltage protection shall satisfy the following requirements

... "c) The time delay selection shall be based on the following conditions: (i) The allowable time delay, including margin, shall not exceed the maximum time delay that is assumed in the FSAR accident analyses ... (iii) The allowable time duration of a degraded voltage condition at all distribution system levels shall not result in failure of safety systems or components;" 1 Enclosure PG&E Letter DCL-11-072 PG&E described its design and how it met these conditions in Reference

2. NUREG-0675 Supplement No.9, Section 8.1, "Low and or Degraded Grid Voltage Condition", summarized the NRC requirements described in References 1 and 2. The current TS 3.3.5.3 SR contains FLUR TS limits that are nonconservative for protection of ESF components during postulated sustained degraded grid voltage conditions in that some ESF equipment could trip on overcurrent and not be able to restart without operator action (Reference 3). The changes proposed in this LAR correct the nonconservative FLUR TS limits contained in the current TS 3.3.5.3 SR. The change involves the use of three discrete voltage/time delay relays, which allows for independent control of the loss of voltage setpoints.

The DCPP Units 1 and 2 safety analyses of record have been evaluated for ESF component actuation time delay that bounds the maximum SLUR time delay, and have been determined to remain within the DCPP licensing basis acceptance criteria.

The proposed amendment would also revise the FSARU to increase ESF component delay times described in the FSARU accident analyses to bound the current maximum SLUR actuation time. The proposed amendment would revise the analysis of record for the LOCA control room operator and offsite dose analysis described in the FSARU to increase the assumed containment spray delay time and to increase the assumed time for closure of the control room normal air intake dampers. Additionally, the proposed revision to the control room operator and offsite dose analysis includes more conservative inputs for the containment spray iodine removal rate, control room normal air inflow rate, control room unfiltered infiltration rate, and distance to the Low Population Zone (LPZ) boundary.

The proposed amendment would also provide a new process for revising input values for the LOCA control room operator and offsite dose analysis.

The implementation plan for the FLUR TS 3.3.5.3.a changes involves new relays and a new relay panel in each 4kV vital bus. To ensure effective planning for this complex change, PG&E will need approval at least three months prior to the start of the implementing refueling outage. Assuming NRC approval by October 21, 2012, the next refueling outage is Unit 2 Refueling Outage 17, starting on February 3, 2013. 2. DETAILED DESCRIPTION Proposed Amendment The following changes are proposed to the TS SR 3.3.5.3: SR 3.3.5.3.a is revised from: a. Loss of voltage Diesel Start Allowable Value 0 V with a time delay of 0.8 2 To: Enclosure PG&E Letter OCL-11-072 seconds and 2583 V with a :s; 10 second time delay. Loss of voltage initiation of load shed with one relay Allowable Value 0 V with a time delay of :s; 4 seconds and 2583 V with a time delay :s; 25 seconds and with one relay Allowable Value 2870 V, instantaneous.

a. Loss of voltage Oiesel Start Allowable Value 0 V with a time delay of :s; 0.8 seconds and 2583 V with a :s; 10 second time delay. Loss of voltage initiation of load shed with relay Allowable Values of:

V for :::;10 sec V for :::;6 sec V for :::;4 sec And one relay Allowable Value of:

V, instantaneous The changes to SR 3.3.5.3 involve a change to a TS Allowable Value (A V) setpoint.

The control of TS setpoints is addressed in Technical Specifications Task Force (TSTF) Traveler TSTF-493, Revision 4, "Clarify Application of Setpoint Methodology for limiting safety system settings (LSSS) Functions," dated January 5, 2010, (ML 100060064) and the associated errata "Transmittal of TSTF-493, Revision 4, Errata," dated April 23, 2010, (ML 101160026).

For TSTF-493, Revision 4, Option A, in which the setpoint values are retained in the TS, the LOP OG Start Instrumentation TS 3.3.5 does not contain any TS changes. TSTF-493, Revision 4, Option A, contains a change to the TS Bases for SR 3.3.5.3 for the LOP OG Start Instrumentation TS 3.3.5. The change to the TS Bases for SR 3.3.5.3 adds the sentence "There is a plant specific program which verifies that the instrument channel functions as required by verifying the as-left and as-found setting are consistent with those established by the setpoint methodology".

This revision to the TS Bases for SR 3.3.5.3 is included in this LAR. The TS and TS Bases changes for other TS to address application of setpoint methodology will be made in a separate future LAR for TSTF-493.

The proposed change would revise FSARU Sections 6.3.3.7, Tables 6.3-7, 6.20-1,6.20-13, 6.20-15,6.20-17, 6.20-21, and Appendix 6.20 to state that the Emergency Core Cooling System (ECCS) loss of offsite power (LOOP) flow delay times were evaluated for an increased delay time from 27 seconds to 42 seconds in order to bound the maximum allowable SLUR time delay. The proposed change would revise the LOOP delay time discussed in FSARU 3 Enclosure PG&E Letter DCL-11-072 Sections 15.3.1,15.3.6, 15.4.1, and 15.4.10 and FSARU Tables 15.3-1, 15.3-2, 15.4.1-1A, 15.4.1-1B, 15.4.1-2A, 15.4.1-2B, 15.4.1-3A, 15.4.1-3B, 15.4.1-7A, and 15.4.1-7B to state a total safety injection (SI) with LOOP/degraded voltage injection delay time of 42 seconds was evaluated in order to bound the maximum 4.16 kV SLUR actuation time delay. It was determined that the additional ECCS delay due to a 4.16 kV SLUR actuation time delay would have an insignificant effect on the small break loss-of-coolant accident (SBLOCA) thermal hydraulic results. The additional time delay due to 4.16 kV SLUR actuation time delay did lead to an increase in the peak cladding temperature (PCT) penalty for Best Estimate large break loss-of-coolant accident (LBLOCA) that is within the 10 CFR 50.46 acceptance criteria.

The proposed amendment would revise the analysis of record for the LOCA control room operator and offsite dose analysis described in the FSARU to bound the maximum potential delays associated with the postulated degraded voltage scenario and include the limiting delays for LOCA initiation to SI signal generation.

The proposed increase to the containment leakage doses result from increasing the assumed containment spray delay time from 86.5 seconds to 106 seconds and increasing the assumed times to close the control room normal air intake dampers from 10 seconds for both units to 18 seconds for the unaffected unit and 44.2 seconds for the unit undergoing a LOCA. This revision to the LOCA control room operator and offsite dose analysis uses more conservative inputs for the containment spray iodine removal rate, control room normal air inflow rate, control room unfiltered infiltration rate, and distance to the LPZ boundary.

The proposed amendment revises inputs to and does not increase the limiting total control room operator or offsite doses. The proposed amendment would provide a new process for revising input values for the FSARU LOCA control room operator and offsite dose analysis.

Plant procedures provide administrative controls for maintaining the recirculation loop leakage input to the total LOCA control room operator and offsite dose analysis in accordance with the TS 5.5.2, "Primary Coolant Sources Outside Containment" Program. Actual measured recirculation loop leakage values are typically much lower than the flow rate limits provided in the FSARU LOCA control room operator and offsite dose analysis.

The proposed change would allow for the administratively controlled recirculation loop leakage to be revised to offset changes to other inputs of the control room operator and offsite dose analysis, as long as the total control room operator and offsite dose values are within the applicable 10 CFR 50 Appendix A, GDC 19-1971 and 10 CFR 100 limits. In summary, the FLUR TS limits are revised in TS 3.3.5.3. Additionally, the FSARU is revised to discuss the increased ESF component delay times which bound the maximum SLUR actuation time delay. 4 Enclosure PG&E Letter DCL-11-072 TS Bases 3.3.5 is revised to include the proposed changes to the FLUR and to address TSTF-493, Revision 4. The TS Bases changes are included for information only. The proposed TS changes are noted on the marked-up TS page provided in Attachment

1. The proposed retyped TS is provided in Attachment
2. The revised TS Bases is contained for information only in Attachment
3. Existing LOP DG Start Instrumentation The DGs provide a source of emergency power when offsite power is either unavailable or is degraded below a point that would allow safe unit operation.

Undervoltage protection will generate an LOP start if a loss of voltage or degraded voltage condition occurs on the 4.16 kV vital bus. There are three LOP start signals, one for each 4.16 kV vital bus. Undervoltage relays are provided on each 4.16 kV Class 1 E vital bus for detecting a sustained degraded voltage condition, or a loss of bus voltage. A relay will generate an LOP signal (first level undervoltage type relay setpoint) if the voltage is below equipment protection thresholds for a short time. The DG start relays (one per bus) will generate an LOP signal with AV of equal to or greater than 0 volts with a time delay of equal to or less than 0.8 seconds and equal to or greater than 2583 volts with equal to or less than a 10 second time delay (Note: This relay is unchanged by this LAR). In addition, the circuit breakers for all loads, except the 4160-480 volt load center transformers, are opened automatically by load shedding relays for first level undervoltage.

Each of the vital 4.16 kV buses has a separate pair of load shed sensing FLURs. The relays have a two-out-of-two logic arrangement for each bus to prevent inadvertent tripping of operating loads, either from a single failure in the potential circuits, or from human error. One relay has an AV of equal to or greater than 2870 volts, instantaneous.

The second of the two relays has an inverse time characteristic and AV equal to or greater than 0 V with a time delay of equal to or less than 4 seconds and equal to or greater than 2583 V with a time delay equal to or less than 25 seconds to prevent loss of operating loads during transient voltage dips, and to permit the offsite power sources to pick up the load. Should there be a sustained degraded voltage condition (second level undervoltage), where the voltage of the vital 4.16 kV buses remains at approximately 3785 volts or below, but above the setpoints of the FLUR, the following second level undervoltage actions occur automatically:

(1 ) After an equal to or less than 10-second time delay, the respective DGs will start. (2) After an equal to or less than 20-second time delay, if the undervoltage condition persists, the circuit breakers for all loads to the respective vital 5 Enclosure PG&E Letter DCL-11-072 4.16 kV buses, except the 4160-480 volt load center transformer, are opened and sequentially loaded on the DG. Each vital 4.16 kV bus has two SLURs operating with a two-out-of-two logic. Each vital 4.16 kV bus also has two second level undervoltage timers. One timer provides the DG start and the other will initiate load shedding.

AV Setpoints The voltage and time delay setpoints protect ESF equipment from loss of function.

The allowable time delay, including margin, should not exceed the maximum time delay assumed in the FSARU accident analyses (FSARU Chapter 6 and 15). The selection of these setpoints is such that adequate protection is provided when all sensor and processing time delays are taken into account. The actual nominal setpoint entered into the relays is normally set more conservative than that required by the AV. AVs are specified for each function in the limiting condition for operation (LCO). The nominal setpoints are selected to ensure that the setpoint measured by the surveillance procedure meets the AV if the undervoltage relay is performing as required.

If the measured setpoint meets the AV, the undervoltage relay is considered OPERABLE.

Operation with a setpoint less conservative than the nominal setpoint, but within the AV, is acceptable provided that operation and testing is consistent with the assumptions of the unit specific setpoint calculation.

Each AV specified is more conservative than the analytical limit assumed in the transient and accident analyses in order to account for instrument uncertainties appropriate to the trip function.

These uncertainties are defined in DCPP design calculations.

The current FLUR TS limits are accepted in NUREG-11 02 for Unit 1 (Reference

4) and NUREG 1132 for Unit 2 (Reference 5). DCPP TS 3.3.5.3 provides a minimum voltage value for the FLUR and SLUR TS limits. PG&E calculation 357S-DC establishes the TS bases, TS minimum voltage and maximum time delay limits and allowable maximum and minimum as-found limits for the FLURISLUR calibration acceptance criteria (Reference 6). The current DCPP SBLOCA analysis was accepted in License Amendment 37/36 (Reference 11). The current LBLOCA analysis for Unit 1 was accepted in License Amendment 191 (Reference 12). The current LBLOCA analysis for Unit 2 was accepted in License Amendment 192 (Reference 13). The current loss of coolant accident (LOCA) Mass and Energy and Containment Integrity analyses were reviewed in the initial safety evaluation for the plant operating licenses (Reference 14). The current DCPP LOCA control room operator and offsite dose analysis results are provided in FSARU Table 15.5-63. The DCPP LOCA dose analysis results 6 Enclosure PG&E Letter OCL-11-072 were previously reviewed by the NRC in License Amendment 80/79 (Reference 15). PG&E has made changes to the LOCA control room operator and offsite dose analysis that implemented tradeoffs of inputs to maintain total dose at the licensing limits provided in GOC 19-1971 and 10 CFR 100. OCPP has since determined that these changes do not meet the criteria of NEI 96-07 for changes that can be made in accordance with 10 CFR 50.59 without prior NRC approval.

NEI 96-07 states that each element of a proposed activity must be screened except in instances where linking elements of an activity is appropriate.

If LOCA dose analysis inputs cannot be considered linked elements, then any input change that results in an increase in limiting dose cannot be performed in accordance with 10 CFR 50.59 when the dose analysis results are at the federal limits. See below for a summary of these changes. In 1998, the LOCA control room operator and offsite dose analysis was revised to correct a non conservative assumption for the containment spray delay time. This change resulted in an increase in the containment leakage portions of the calculated control room operator and offsite doses. The recirculation loop leakage dose portions of the control room operator and offsite doses were decreased in order to maintain the total doses at the GOC 19-1971 and 10 CFR 100 limits. In 2004, the LOCA control room operator and offsite dose analysis was revised to increase the allowable closure time of the control room normal air inlet dampers from five seconds to ten seconds. This change resulted in an increase in the containment leakage dose portions of the calculated control room 'operator and offsite doses. The recirculation loop leakage dose portions were decreased in order to maintain the total doses at the GOC 19-1971 and 10 CFR 100 limits. In 2009, the LOCA control room operator and offsite doses were recalculated to increase the assumed delay for the start of residual heat removal (RHR) pump seal leakage from 23.7 minutes to 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after LOCA initiation.

This change resulted in a decrease in the RHR pump seal leakage dose portion of the calculated control room operator and offsite doses. The recirculation loop leakage dose portions were increased in order to maintain the total doses at the GOC 19-1971 and 10 CFR 100 limits. 7 Purpose for Proposed Amendment Enclosure PG&E Letter DCL-11-072 This LAR addresses violations received during a Component Design Basis Inspection (CDBI) (Reference 7). The current TS 3.3.5.3 SR contains FLUR TS limits that are nonconservative during postulated non-mechanistic sustained degraded 4.16 kV vital bus voltage conditions.

While analyzing the consequences of non-mechanistic scenarios (LOCA and sustained degraded 4.16 kV vital bus voltage) postulated during the CDBI, PG&E concluded both units were in an unanalyzed condition that significantly degraded plant safety, and therefore, reported the condition under 10 CFR 50. 72(b )(3)(ii)(B).

The postulated condition could have resulted in permanently connected class 1 E pump motors tripping overcurrent relays due to sustained degraded voltage on the startup offsite power source. Given a non-mechanistic voltage degradation condition such that voltage remained above the FLUR setting of equal to or greater than 2583 volts and below the SLUR setting of equal to or greater than 3785 volts, permanently connected class 1 E pump motors would experience this degraded voltage for up to the SLUR time delay relay setting of equal to or less than 20 seconds. Prior to reaching the SLUR time delay setpoint and initiating load transfer to the onsite emergency DGs, operating motors (e.g., auxiliary saltwater pump and component cooling water pumps) could trip on overcurrent.

PG&E implemented compensatory measures by changing the FLUR setpoints on the vital buses of both Units 1 and 2, thus protecting safety-related motors from tripping on overcurrent during postulated sustained degraded voltage conditions.

Specifically, the FLUR delay time was changed such that load shedding and bus transfer would be initiated prior to time-overcurrent tripping of the individual loads (Reference 3). This LAR establishes conservative TS SR 3.3.5.3.a undervoltage relays settings that will ensure availability of ESF equipment by eliminating the potential for degraded voltage related time-overcurrent trips prior to transfer to the DG. Additionally, during the CDBI it was determined that DCPP did not meet the PG&E commitment that requires that the allowable SLUR time delay, including margin, shall not exceed the maximum time delay that is assumed in the FSARU accident analyses (Reference 1). The existing FSARU Chapters 6 and 15 accident analyses assume that full ECCS injection flow be achieved within 27 seconds after the SI signal is actuated.

This includes the time for the DGs to start and reach rated speed, and for all loads to be sequenced.

The FSARU analyses are based on a worst-case design basis event concurrent with a loss of offsite power. The effect of the current SLUR time delay setpoint of 20 seconds exceeds the maximum time delay considered in the FSARU accident and LOCA 8 Enclosure PG&E Letter DCL-11-072 control room operator and offsite dose analysis assumptions.

The SLUR actuation during the postulated sustained degraded voltage conditions and the increase in the ESF delay times represents a malfunction of an structure, system, and component (SSC) with a different result per 10 CFR 50.59 and is being submitted for prior NRC approval.

The changes to the LOCA control room operator and offsite dose analysis is considered to be a more than minimal increase in the consequences of an accident previously evaluated in the FSARU per 10 CFR 50.59. The changes proposed in this LAR correct the nonconservative FLUR TS limits contained in the current TS 3.3.5.3 SR. The proposed amendments would revise the FSARU to increase ESF component delay times used in the FSARU accident analyses to bound the current maximum SLUR actuation time delay. The proposed amendment would revise the results for the LOCA control room operator and offsite dose analysis of record described in the FSARU and provides a new process for revising inputs to this analysis.

3. TECHNICAL EVALUATION 3.1 SR 3.3.5.3 Design Basis Revision to FLUR TS SR 3.3.5.3 Limits The load shed sensing FLURs will be replaced.

The channel incorporating the time delay will be changed from an inverse time continuous undervoltage function to three discrete voltages and time delays. Figure 1 illustrates the undervoltage protection load shed logic. Figure 2 graphically compares the proposed versus existing setpoint allowable limits. New FLUR TS limits were evaluated in PG&E Design Calculation 357S-DC contained in Attachment 6 to this enclosure.

9 Enclosure PG&E Letter DCL-11-072 Figure 1. A block diagram showing the function of each relay and the analytical limits associated with voltage dropout and time delay settings.

FLUR Percent Bus Voltage 27H*T2 I

{-"\ (Analytical Limit:;::

3411 VAC) j I I

-+:...........,-(An-al-y-ti*-cal-L-hru-*-t:-;::-3-32-g-V-A-C--s:-1-0 -Se-c--')

'-l 2/2 801).11 27H*TIA (Analytical Limit:;::

3120 VAC -::;.6 Sec) 27H*TIB -(Anal}1ical Limit:;::

2704 VAC -:; 4 Sec) 27H*TIC 10 Figure 2. Graphical comparison of existing and proposed undervoltage setpoint AVs Enclosure PG&E Letter DCL-11-072 100 -Existing Versus Proposed FLUR Load Shed Limits 90 -+ --------+ I 80 -1 ....................

on ................................

on ..... : ** : : ... : : : : : : : : : : : : : .... ". --* ___

"". 0 70 t-----------------::.-I!:.

' CD ,.. --------lIi

_----.--------------

I ..... -----Q) en S50 -o > -m o 30 10 -o o Ii I I I ,m rl I , I

  • I 5 ./ ,..."" .. / // ,... .........

10 Time (Sec) 15 20 11 25 --+--Current TS Ch 1 (See Note) ---m---Current TMOD Ch 1 (See Note) ¥--Proposed TS Ch 1 --Current TS Ch 2 ---A---Current TMOD Ch 2 e--Proposed TS Ch 2 -+ -SLUR (No Change) Note: The existing TS SR 3.3.5.3(a) only defines a minimum voltage for 4 Sec and 25 Sec. The intermediate points shown are typical for the actual setpoint response First Level Undervoltage Load Shed Relays Enclosure PG&E Letter DCL-11-072 The selection of the FLUR setpoints is based on the voltage requirements of the ESF loads. The functional safety requirement of the FLURs is to protect ESF equipment from loss of function by initiating the necessary actions required to transfer the safety related buses to the onsite alternating current power sources. The setpoints of the proposed FLUR load shed undervoltage relays, T1 A, T1 B, 11 C, and T2, have different analytical limits (See Figure 1). T2, which is an instantaneous (i.e. no intentional delay) relay, will continue to function like a permissive for the time delay channel (i.e. T1A, T1 B, and T1 C). Load shed will only occur if the bus voltage continues to degrade below the T2 setpoint and further degradation is sensed by T1A, T1 B, or T1 C undervoltage relays. The three T1 relays are setup in a tiered configuration such that T1 A will actuate at the highest voltage but will have the longest time delay of the three, T1 C will have the lowest actuation voltage and the shortest time delay, and T1 B is between the other two. The configuration of three discrete voltage/time delay relays is preferred over a continuous medium inverse voltage time function because it allows for independent control of the loss of voltage setpoint and the coordination with the SLURs. PG&E has analyzed the coordination between motor overcurrent protection settings and the 4.16 kV bus undervoltage protection scheme and verified that the FLUR/SLUR bus undervoltage protection function actuates before individual motor overcurrent protective devices. Thus, a sustained degraded voltage condition will not result in the loss of an ESF function (Reference 8). In order to preclude spurious trips of the offsite power source, the FLUR load shed function will continue to employ a two-out-of-two coincidence logic scheme (Le., T1A, T1 B, T1 C plus T2). A PG&E design calculation has analyzed the dynamic response of the immediately available startup offsite power circuit under various accident scenarios and anticipated operational occurrences, including a dual unit trip. This analysis concluded that the preferred power supply has adequate voltage to start and operate the required loads given the proposed setpoints (Reference 9). A PG&E design calculation establishes the TS minimum voltage and maximum time delay limits and allowable maximum and minimum as-found values for the FLURISLUR calibration acceptance criteria (Reference 6). The Channel Uncertainty (CU) is calculated as follows: CU = Channel Uncertainty

-The total uncertainty of an instrument channel. This is the minimum allowable difference between the design value and the nominal setpoint value. 12 Enclosure PG&E Letter DCL-11-072 RCA = Rack Component or "String" Calibration Accuracy.

RMTE = Rack Component or "String" Measuring and Test Equipment Uncertainty.

RD = Rack Component or "String" Drift or Stability.

RME = Rack Component or "String" Miscellaneous Effects. RTE = Rack Component or "String" Ambient Temperature Effects. The CU is calculated at 95 percent probability of actuation.

That means there is a 2.5 percent chance that the relay will actuate below "setpoint

-uncertainty" and 2.5 percent chance that the relay will actuate at above "setpoint

+ uncertainty." Therefore, at the point of concern, which is the lower limit, there is 97.5 percent chance that the relay will actuate above "setpoint

-uncertainty." Since the coincident logic for actuation of load shed has to wait until actuation of one of the T1 relays, the lower tail of uncertainty distribution of T1 setpoint will be at 97.5 percent confidence level. The coincident logic is based on the actuation of T1 A (Reference 6). The changes to SR 3.3.5.3 involve a change to a TS AV setpoint.

The control of TS setpoints is addressed in Technical Specifications Task Force (TSTF) Traveler TSTF-493, Revision 4, "Clarify Application of Setpoint Methodology for LSSS Functions," dated January 5, 2010, (ML 100060064) and the associated errata "Transmittal of TSTF-493, Revision 4, Errata," dated April 23, 2010, (ML 101160026).

The NRC announced the availability of model applications (with model no significant hazards consideration determinations) of the options for plant-specific adoption of TSTF-493, Revision 4, in the Federal Register on May 11, 2010 (FR volume 75, number 90, page 26294). For TSTF-493, Revision 4, Option A, in which the setpoint values are retained in the TS, the LOP DG Start Instrumentation TS 3.3.5 does not contain any TS changes. TSTF-493, Revision 4, Option A, contains a change to the TS Bases for SR 3.3.5.3 for the LOP DG Start Instrumentation TS 3.3.5. The change to the TS Bases for SR 3.3.5.3 adds the sentence "There is a plant specific program which verifies that the instrument channel functions as required by verifying the as-left and found setting are consistent with those established by the setpoint methodology." This revision to the TS Bases for SR 3.3.5.3 is included in this LAR. In PG&E Letter DCL-07-002, "License Amendment Request 07-01, Revision to Technical Specifications to Support Steam Generator Replacement," dated January 11, 2007, PG&E made a commitment to the NRC regarding the setpoint methodology.

PG&E committed to submit changes related to the setpoint methodology to the NRC once the TSTF-493, "Clarify Application of Setpoint 13 Enclosure PG&E Letter DCL-11-072 Methodology for LSSS Functions," is approved by the NRC. The TS and TS Bases changes for other TS to address application of setpoint methodology will be made in a separate future LAR for TSTF-493.

The calculation supporting the revised TS SR 3.3.5.3.a limits, 357S-DC, is provided in Attachment

6. The calculation includes the basis for the proposed AV and the limiting acceptable values for the as-found tolerance band and the as-left tolerance band. The acceptable as-found (AAF) values are the larger of the sensor calibration accuracy or the sensor drift plus the sensor measuring and test equipment uncertainty.

The acceptable as-left (AAL) values are the larger of the vendor uncertainty or the rack calibration accuracy.

The TS setpoints for the FLUR loss of voltage diesel start relays are not changed. For completeness, the TS SR 3.3.5.3 loss of voltage diesel start AV, nominal trip setpoints (NTSP), AAF, and AAL for voltage and time settings are as follows: Relay 27H*B2-27P Low Voltage Diesel Start AV Vi AV T1 NTSP Vi AAL Vi AAF Vi NTSP T1 AAL T1 AAF T1 Greater than or equal to 2583 V (62 percent) Less than or equal to 10 Seconds At relay 76.3 V; at bus 2667 V (approximately 64 percent) At relay +/- 1.48 V; at bus approximately

+/- 52 V At relay +/- 1.53 V; at bus approximately

+/- 54 V 4.7 Seconds +/- 0.3 Seconds +/- 0.3 Seconds Relay 27H*B2-27X Loss of Voltage Diesel Start AV V2 AV T2 NTSP V2 AAL V2 AAF V2 NTSP T2 AAL T2 AAF T2 Greater than or equal to 0 V (0 percent) Less than or equal to 0.8 Seconds At relay 23.4 V; at bus 818 V (approximately 19.7 percent) At relay +/- 0.46 V; at bus approximately

+/- 17 V At relay +/- 0.64 V; at bus approximately

+/- 22 V 0.65 Seconds +/- 0.05 Seconds +/- 0.05 Seconds Relay 27H*B2-127P Low-Low Voltage Diesel Start is not a TS relay and is not listed here. See Attachment

6. The TS SR 3.3.5.3 loss of voltage initiation of load shed includes one instantaneous load shed relay (27H*T2) that is set at higher voltage with respect to the time delay relays. The instantaneous relay has an AV of 3411 V (82 percent), NTSP of 3448 and higher, an AAL tolerance of +/- 18 V, and AAF 14 Enclosure PG&E Letter DCL-11-072 tolerance of +/- 22 V. There are three time delay relays with the following AV, NTSP, AAL, and AAF for voltage and time settings:

Relay 27H*T1A Low Voltage Load Shed AV ViA AV T1A NTSP ViA AAL ViA AAF ViA NTSP T1A AAL T1A AAF T1A Greater than or equal to 3328 V (80 percent) Less than or equal to 10 Seconds At relay 96.5 V; at bus 3373 V (approximately 81 percent) At relay +/- 0.5 V; at bus approximately

+/-18 V At relay +/- 0.62 V; at bus approximately

+/- 22 V 8 Seconds +/- 1 Second +/- 1 Second Relay 27H*T1 B Low-Low Voltage Load Shed AV V1B AV T1B NTSP V1B AAL V1B AAF V1B NTSP T1B AAL T1B AAF T1B Greater than or equal to 3120 V (75 percent) Less than or equal to 6 Seconds At relay 90.5 V; at bus approximately 3163 V (76 percent) At relay +/- 0.5 V; at bus approximately

+/- 18 V At relay +/- 0.59 V; at bus approximately

+/- 21 V 5 Seconds +/- 0.7 Seconds +/- 0.7 Seconds Relay 27H*T1 C Loss of Voltage Load Shed AV ViC AV TiC NTSP ViC AAL ViC AAF ViC NTSP TiC AAL TiC AAF TiC Greater than or equal to 2704 V (65 percent) Less than or equal to 4 Seconds At relay 78.6 V; at bus 2747 V (approximately 66 percent) At relay +/- 0.5 V; at bus approximately

+/- 18 V At relay +/- 0.54 V; at bus +/- 19 V 3 Seconds +/- 0.5 Seconds +/- 0.5 Seconds The AV, NTSP, AAL, and AAF values are provided in calculation 357S-DC (Reference 6). At DCPP, setpoints are controlled using a graded approach by following PG&E Inter-Departmental Administrative Procedure (IDAP) CF6.ID1, "Setpoint Control Program," a procedure subject to 1 0 CFR 50.59. CF6.ID1 requires that electrical setpoints shall be fully documented by a calculation performed using a specified methodology.

For DCPP, the Corrective Action Program (CAP) procedure is PG&E Program Directive OM7, "Corrective Action Program," and problems are documented per DCPP IDAP OM7.ID1, "Problem Identification and Resolution." The CAP includes a process to perform a TS operability review, and document as 15 Enclosure PG&E Letter DCL-11-072 necessary per DCPP IDAP OM7.ID12, "Operability Determination," and to determine the necessary corrective actions to be taken, including corrective actions to prevent recurrence, per OM7.ID1. An issue is entered as a notification into a computer based tracking program. SR 3.3.5.3 is performed for the SR 3.3.5.3 requirements using surveillance test procedures that are subject to 10 CFR 50.59. The current surveillance test procedures for SR 3.3.5.3, STP M-75F, STP M-75G, and STP M-75H, require that if the as-found data for the setpoints are not within desired, to notify the operations shift foreman and to initiate a notification.

The current surveillance test procedures for SR 3.3.5.3 also require that the as-left data shall be within a desired range. The instrument channel cannot be returned to service and declared operable unless the setpoint can be reset to within the as-left setpoint and the evaluation of the channel shows it is functioning as required.

In order to ensure control of the setpoints for the proposed changes to TS SR 3.3.5.3 and the TS SR 3.3.5.3 Bases, the 10 CFR 50.59 controlled surveillance test procedures applicable to TS SR 3.3.5.3 will be updated as required as part of implementation of the amendment for each unit. The Actions for the various potential surveillance outcomes will be required as follows: (1) The instrument channel setpoint exceeds the as-left tolerance but is within the as-found tolerance:

  • Reset the instrument channel setpoint to within the as-left tolerance;
  • If the instrument channel setpoint cannot be reset to a value that is within the as-left tolerance around the instrument channel setpoint at the completion of the surveillance, if not already inoperable, the instrument channel shall be declared inoperable.

(2) The instrument channel setpoint exceeds the as-found tolerance but is conservative with respect to the TS AV:

  • Reset the instrument channel setpoint to within the as-left tolerance;
  • If the instrument channel setpoint cannot be reset to a value that is within the as-left tolerance around the instrument channel setpoint at the completion of the surveillance, if not already inoperable, the instrument channel shall be declared inoperable;
  • Enter the channel's as-found condition in the CAP for prompt verification that the instrument is functioning as required, and for further evaluation.

Evaluate the channel performance utilizing available information to verify that it is functioning as required before returning the channel to service. 16 Enclosure PG&E Letter DCL-11-072 The evaluation may include an evaluation of magnitude of change per unit time, response of instrument for reset, previous history, etc., to provide confidence that the channel will perform its specified safety function;

(3) The instrument channel setpoint is non-conservative with respect to the TS AV:

  • Reset the instrument channel setpoint to within the as-left tolerance;
  • Enter the channel's as-found condition in the CAP for evaluation.

Evaluate the channel performance utilizing available information to verify that it is functioning as required before returning the channel to service. The evaluation may include an evaluation of magnitude of change per unit time, response of instrument for reset, previous history, etc., to provide confidence that the channel will perform its specified safety function.

These procedural actions are the minimum actions which the procedures will require and additional actions may be taken. These procedural actions will apply until procedural actions consistent with a license amendment for TSTF-493, Revision 4, are implemented for all automatic protective devices related to variables having significant safety functions as delineated by 10 CFR 50.36(c)(1

)(ii)(A).

In addition, the "Equipment Control Guidelines" (ECGs) will be updated as part of implementation of the amendment for each unit to identify the methodologies used to determine the as-found and as-left tolerances.

The ECGs are documents controlled under 10 CFR 50.59 and are incorporated into the Final Safety Analysis Report (FSAR) by reference.

3.2 Evaluation of Impact of SLUR Time Delay on Accident Analysis During an NRC CDBI (Reference 7), it was identified that, contrary to license basis requirements summarized in the DCPP SSER 9 Section 8.1, the 230 kV undervoltage relay delay setpoints are not bounded by the current DCPP FSAR accident analyses.

SSER 9 states "The allowable time delay, including margin, shall not exceed the maximum time delay that is assumed in the FSAR accident analyses." The plant safety analyses have been evaluated to determine the impact of a longer time delay and determined that the analysis acceptance criteria continues to be met. Postulating a sustained 230 kV degraded voltage results in increasing ESF component delay times beyond what has previously been evaluated.

17 Enclosure PG&E Letter OCL-11-072 Immediately after the successful transfer to the 230 kV offsite power source, the postulation of a non-mechanistic condition is assumed to occur which results in sustained degraded voltage just above the FLUR setpoint and just below the SLUR setpoint.

Twenty seconds after the degraded voltage occurs, the 230 kV SLUR actuates and sheds the 4.16 kV electrical loads from the 230 kV System thereby resulting in a LOOP. The emergency diesel generators are already operating at rated speed and connect to the vital 4.16 kV buses and begin to sequence the ESF components onto the appropriate buses. The current DCPP FSAR accident analyses do not model the system response for this scenario and therefore do not bound the ESF component operation times that could occur during this scenario.

Consistent with the current safety analysis of record (AOR), the ESF delay evaluations for the postulated sustained undervoltage do not credit any ESF functions to operate until after the SLUR actuation occurs and the diesel generators have loaded onto the 4.16 kV vital buses. As stated in Section 3.1 of this LAR, PG&E has analyzed the coordination between motor overcurrent protection settings and the 4.16 kV bus undervoltage protection scheme and verified that the FLURISLUR bus undervoltage protection function actuates before individual motor overcurrent protective devices. Thus, a sustained degraded voltage condition will not result in the loss of an ESF function.

The SLUR actuation during the postulated sustained degraded voltage conditions and the increase in the ESF delay times represents a malfunction of an SSC with a different result under 10 CFR 50.59 and is being submitted for prior NRC approval within this LAR. The OCPP Units 1 and 2 safety AOR were evaluated for the increased ESF actuation time delays as listed in Table 1. Table 2 lists all of the OCPP safety analyses and identifies that most of the analyses were not impacted since they do not credit any of these ESF functions for mitigation or are bounding based on assuming a loss of offsite power does not occur. Table 2 also identifies which analyses were not significantly impacted such that the current FSARU analyses remains bounding for the increased ESF delay times. Table 2 identifies that four analyses were evaluated for impact due to the increased ESF delay times, and a summary of these evaluation results has been provided.

Consequently, the applicable FSARU sections related to these safety analyses in Appendix 6.20 and Sections 6.3, 15.3, and 15.4 have been updated to reflect the new ESF actuation time delays. 18 Small Break LOCA Enclosure PG&E Letter DGL-11-072 The DGPP Units 1 and Unit 2 limiting SBLOGA cases were evaluated for the increased ESF delay time for the auxiliary feed water (AFW) and EGGS injection flow. The core uncovery and PGT for the limiting SBLOCA case occur at 12 to 15 minutes into the event. The slight decrease in EGGS flow due to the 15-second increase in the delay time was determined to be small compared to the total amount of EGGS injection flow that has entered the reactor coolant system (RGS) up to the time of core uncovery.

Similarly, the 5-second increase in the AFW actuation time was determined to have a negligible impact on the thermal hydraulic results since the major source of decay heat removal is due to the RGS flow out of the break. Therefore, it was concluded that the increased EGGS and AFW delay times have a negligible impact on the results such that the current SBLOGA 10 CFR 50.46 PGT and core oxidation results remain bounding (Reference 10). Large Break LOCA Both DGPP Units 1 and 2 use a best estimate LBLOGA evaluation methodology for the AOR. The LBLOGA evaluation considered an increase in EGGS injection flow delay time from 27 seconds to 42 seconds. The primary effect of increasing the EGGS delay time is that it can lead to increased duration of fuel heatup periods during the refill and reflood periods. The blowdown remains unaffected since this phase is over before the EGGS injection flow begins. Depending on the break size and the accumulator pressure and volume, the end of the refill and periods and the accumulator injection can vary and create periods with significantly different and/or reduced EGGS injection flow. Because refill ends earlier in cases with larger break sizes, the reflood heatup also begins earlier. With the increased delay time, this can create a period of reduced ECGS injection flow during the beginning of reflood heatup when compared to the current AOR cases. As a result, the cladding is assumed to go through a period of additional heatup compared to the current cases. This additional heatup period is conservatively assumed to be equal to the time it takes for the delayed EGGS injection flow to compensate for the reduction in initial injection flow water mass compared to the current case. As a result of the increased EGGS injection flow delay, the fuel rods will experience longer periods of heatup during reflood and this increased temperature is estimated to directly increase the PGT. In order to quantify this temperature increase, the delay in the end of the refill/reflood periods and the associated heatup rates were calculated.

For Unit 1, the evaluation was based on global model runs with an effective break size area greater than the reference transient.

These greater break areas will depressurize the RGS faster leading to a more rapid accumulator blowdown and are more likely to result in a delay between the accumulator injection and the start of EGGS injection flow. The cases were selected to evaluate the relative 19 Enclosure PG&E Letter DCL-11-072 effects of accumulator volume, accumulator pressure, and break size. The limiting evaluation case for Unit 1 was determined to have a high discharge coefficient (greater effective break size) and minimum accumulator volume which resulted in a faster accumulator blowdown and which created a longer period of reflood with significantly reduced ECCS flow. This evaluation case resulted in a o of penalty for the early Reflood 1 period and an estimated 39 of penalty for the Reflood 2 period. As shown in Table 3 with these PGT penalties applied to the current 10 CFR 50.46 PCT rackup sheet for Unit 1, the resulting PCT, 1975 of, still remains well below the 2200 of limit. Since the Unit 1 AOR oxidation calculations are based on an oxidation transient with a PCT value of 2238 of, which continues to bound the Unit 1 PCT results, the AOR maximum local oxidation and core-wide oxidation calculations are not impacted and remain valid. Unit 2 uses the newer ASTRUM best estimate LBLOCA methodology, which does not track the individual Reflood 1 and Reflood 2 penalties but only reports one overall reflood penalty. For Unit 2, the evaluation was also based on selecting cases with higher break sizes that depressurize faster and lead to a faster accumulator blowdown that create a greater potential for a delay between accumulator injection and EGCS injection.

The evaluation also considered cases with high accumulator pressure or low accumulator volume which could also lead to a faster accumulator blowdown.

The evaluation for the limiting case concluded there is a net PCT penalty of 16 of due to the increased ECCS injection flow delay time. As shown in Table 3 with this PCT penalty applied to the current 10 CFR 50.46 PCT rackup sheet for Unit 2, the resulting PCT, 1888 of, still remains well below the 2200 of limit. For the maximum local oxidation it was concluded there would be negligible additional oxidation to the calculated 1.64 percent equivalent cladding reacted (ECR) and that there is still significant margin to the allowable 17 percent acceptance criterion.

For the core wide oxidation, it was concluded that there is a small potential increase in hot assembly oxidation and the calculated 0.17 percent value, but that it remains below the 1 percent acceptance criterion.

In conclusion, the evaluations for the impact of the increased ECGS injection delay time which bound the SLUR actuation time conclude that the Unit 1 and Unit 2 LBLOCA results remain well within the 10 GFR 50.46 acceptance criteria (Reference 10). LOCA Containment Integrity The evaluation for the increased ESF delay times was based only on the Unit 2 analyses since they bound the Unit 1 results. The increased ESF delay times were evaluated for both the effect on the calculated LOCA mass and energy release and the effect on the containment integrity peak pressure and temperature results. The limiting cases evaluated were the double ended hot leg (DEHL) break and double ended pump suction (DEPS) break with minimum 20 Enclosure PG&E Letter DCL-11-072 ECCS since they generate the peak pressure and temperature values currently reported in the DCPP FSARU. The evaluation results for these limiting Unit 2 cases are summarized in Table 4 which shows that the peak pressure for the DEHL break increased 0.3 psi to 41.7 psig and the peak temperature increased 0.5 of to 262.3 of. However, these peak values continue to be well within the containment design limits of 47 psig and 271°F. Additionally, the peak pressure results remain below the value of P a = 43.5 psig as established in TS 5.5.16, such that there is no impact on the TS or containment leakage rate testing program (Reference 10). Table 1: ESF Delay Times to Bound SLUR Actuation Time Engineered Safeguards Function Current Revised (ESF) FSARU FSARU Delay time Delay Time (sec) (sec) Emergency Core Cooling System 27 42 (ECCS) Injection Flow Containment Fan Cooler Unit (CFCU) 48 52 Heat Removal Auxiliary Feed Water (AFW) Flow 60 65 Containment Spray (CS) Flow 80 100 Note: ESF delay times are relative to the applicable initiating protection signal credited in the safety analysis.

Table 2 Summary of FSARU Safety Analysis Impacts for Increased ESF Delays FSAR FSAR Accident Description Not Evaluated Evaluated Section Impacted FSARU for ESF Still Impact Bounding 15.2.1 Rod Cluster Withdrawal from NoSI Subcritical (RWFS) 15.2.2 Rod Cluster Withdrawal at Power NoSI (RWAP) 15.2.3 Rod Cluster Control Assembly NoSI Misoperation 15.2.4 Uncontrolled Boron Dilution NoSI 15.2.5 Partial Loss of Forced Reactor NoSI Coolant Flow (PLOF) 15.2.6 Startup of an Inactive Reactor NoSI Coolant Loop (SUIL) 15.2.7 Loss of External Electrical Load NoSI and/or Turbine Trip (LOLITT) 21 FSAR FSAR Accident Description Section 15.2.8 Loss of Normal Feedwater (LONF) 15.2.9 Loss of Offsite Power to the Station Auxiliaries (LOAC) 15.2.10 Excessive Heat Removal Due to Feedwater System Malfunctions (FWM) 15.2.11 Sudden Feedwater Temperature Reduction (FWTR) 15.2.12 Excessive Load I ncrease Incident (ELI) 15.2.13 Accidental Depressurization of the Reactor Coolant System (ADRCS) 15.2.14 Accidental Depressurization of the Main Steam System (ADMS) 15.2.15 Spurious Operation of the Safety Injection System at Power (SSI) 15.3.1 Small Break Loss of Reactor Coolant (SBLOCA) 15.3.2 Minor Secondary System Pipe Breaks 15.3.3 Inadvertent Loading of a Fuel Assembly 15.3.4 Complete Loss of Forced Reactor Coolant Flow 15.3.5 Single Rod Cluster Control Assembly Withdrawal at Full Power (Single RWAP) 15.4.1 Major Reactor Coolant System Pipe Ruptures (LBLOCA) 15.4.2.1 Major Secondary System Pipe Rupture Feed Line Break (FLB) 15.4.2.2 Major Secondary System Pipe Rupture Main Steam Line Break (MSLB) 15.4.2.3 Major Secondary System Pipe Rupture MSLB at power 15.4.3 Steam Generator Tube Rupture (SGTR) 15.4.4 Single Reactor Coolant Pump Locked Rotor (LR) 22 Not Impacted No SI No SI NoSI NoSI No SI No SI / ESF No LOOP No LOOP NoSI NoSI NoSI No SI / ESF No SI Enclosure PG&E Letter DCL-11-072 Evaluated Evaluated FSARU for ESF Still Impact Bounding X X X X X X FSAR FSAR Accident Description Section 15.4.5 Fuel Handling Accident (FHA) 15.4.6 Rod Cluster Control Assembly Ejection (RE) 15.4.7 Rupture of a Waste Gas Decay Tank 15.4.8 Rupture of a Liquid Holdup Tank 15.4.9 Rupture of Volume Control Tank 15.4.10 Drop Scenario for Cask Pit Temporary Rack and Platform App LOCA Mass and Energy 6.2.0.2 App MSLB Mass and Energy 6.2.0.3 App LOCA Containment Integrity 6.2.0.4.1 App MSLB Containment Integrity 6.2.0.4.2 3.6 LOCA Forces Not Impacted NaSI No SI / ESF NaSI NoSI NoSI No SI No LOOP No LOOP No SI / ESF Enclosure PG&E Letter OCL-11-072 Evaluated Evaluated FSARU for ESF Still Impact Bounding X X Table 3 Summary of LBLOCA PCT Penalties for Increased ESF Delay Times Current PCT Penalty Revised PCT AORPCT for ESF Delay per 10 CFR (OF) (1) (OF) 50.46 (OF) Unit 1 Reflood 1 1990 0 1990 Unit 1 Reflood 2 1936 39 1975 Unit 2 1872 16 1888 (1) Includes AOR plus the current PCT penalties tracked per 10 CFR 50.46. Table 4 LOCA Containment Integrity Results for Increased ESF Delay Times Current FSARU Revised for ESF Delay Break Location Peak Pressure Peak Pressure (psig) (psig) OEHL 41.4 @ 23.8 sec 41.7 @23.5sec OEPS min ECCS 39.8 @ 24.1 sec 39.8 @ 23.5 sec Break Location Peak Temperature Peak Temperature 23 Current FSARU DEHL DEPS min EC Enclosure PG&E Letter DCL-11-072 Revised for ESF Delay 262.3 259.3 Note: Re,sults are based on limiting Unit 2 cases. 3.3 Evaluation of Impact of SLUR Time Delay on LOCA Dose Analysis The LOCADOSE code is used to predict LOCA doses at the control room, the Exclusion Area Boundary (EAB) and the LPZ. The leakage pathways contributing to dose consist of leakage from the containment, normal leakage from post LOCA recirculation path piping in the Auxiliary Building (termed expected leakage), and leakage from a failed RHR pump seal assumed to occur 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after the LOCA. In addition, operations personnel in the control room are assigned a fixed control room egress/ingress dose. Additional analyses are performed to develop dose rates per gpm of post LOCA recirculation loop leakage in either filtered or unfiltered locations of the Auxiliary Building.

The results of these calculations are then used with the available dose margin to federal limits to determine the allowable leakage rates for the administratively controlled ABVS filtered and unfiltered post LOCA recirculation loop leakage. The limiting location provides the acceptance criteria for operational post LOCA recirculation leakage that is routinely identified and tracked via a plant procedure.

The proposed change revises inputs to the LOCA control room operator and offsite dose analysis.

The increases in the containment leakage inputs are offset by decreases in the recirculation loop leakage such that the total control room operator dose remains within the 10 CFR 50 Appendix A, GDC 19-1971 and 10 CFR 100 limits. The proposed change decreases the total offsite dose, as the recirculation loop leakage is decreased to align with that assumed in the control room operator dose analysis.

The recirculation loop leakage is administratively controlled by plant procedures in accordance with TS 5.5.2, Primary Coolant Sources Outside Containment.

24 Enclosure PG&E Letter DCL-11-072 Specifically, the proposed change increases the containment leakage input due to the changes discussed below: (1) The proposed revision decreases the containment spray iodine removal rate from 31 h(1 to 29 h(1. (2) The proposed revision decreases the LPZ boundary distance from 10 kilometers to 6 miles for the LOCA LPZ calculation.

To be consistent with the 6 mile LPZ boundary distance change, the following LPZ atmospheric dispersion factors (X/Q) are increased:

(2)(b )(i) 0-8 hour: from 2.2E-5 to 2.4E-5 s/m 3 (2)(b)(ii) 8-24 hour: from 4.75E-6 to 4.8E-6 s/m 3 (3) The proposed revision increases the delay time for CS delivery time from 86.5 seconds to 106 seconds (which includes a six second delay from LOCA initiation to SI signal generation).

The spray delay time of 86.5 seconds assumed in the AOR is calculated based on time to signal initiation, diesel generator start time, the sequence load time, and containment spray pipe fill time. The 86.5 second delay was reported to the NRC via a routine 10 CFR 50.59 report via PG&E Letter DCL-02-049 dated April 26, 2002 (Reference 16). The 106 second spray delay is comprised of a limiting delay of 6 seconds between LOCA initiation and SI signal generation per FSARU Table 15.4.1-1 B and a limiting delay of 100 seconds between the SI signal generation time and start of containment spray into containment.

(4) The proposed revision increases the initial Control Room Ventilation System (CRVS) outside air intake flow rate for normal (Mode 1 operation) from 2100 scfm to 4200 scfm. The subject AOR assumes that the initial outside air intake flow rate is increased from 2100 scfm total to 2100 scfm per unit, or 4200 scfm total. This intake flow rate is reduced to 2100 scfm total when the non LOCA unit inlet dampers are assumed to close. (5) The proposed revision increases the delay time of the normal CRVS inlet damper closure from 10 seconds to 18 seconds on the unit not experiencing the LOCA, and from 10 seconds to 44.2 seconds on the unit experiencing the LOCA. 25 Enclosure PG&E L-etter DCL-11-072 The current damper closure delay time for both units is ten seconds from receipt of the 81 actuation signal, which is assumed to occur at time zero. In addition the following damper closure delays to both units' dampers are made: 1) a limiting delay of six seconds between LOCA initiation and 81 signal generation per F8ARU Table 15.4.1-1 B, and 2) a limiting delay of two seconds between the 81 signal generation time and 81. Additionally, the closure of the LOCA unit's intake dampers will be delayed until DG start and loading due to postulated degraded 230 kV voltage. The DGs are assumed to load onto the 4 kV buses at 26.2 seconds after 81 actuation.

(6) The proposed revision increases the assumed control room unfiltered infiltration rate from 10 scfm to 70 scfm. Previously, 10 scfm was assumed for unfiltered infiltration.

The current F8ARU Post LOCA doses are below: CONTROL ROOM OPERATOR DOSES (REM) Pathway Thyroid Containment leakage 5.96 RHR pump seal leakage 0.022 Expected recirculation loop leakage 0.85 Recirculation loop leakage: 1.85 gpm, with charcoal filtration, or 0.186 gpm, with no filtration 18.45 Plume radiation (egress-ingress) 4.72 Other direct radiation pathways 0.00 TOTAL CONTROL ROOM OPERATOR DOSES 30.00 10 CFR 50 APPENDIX A, GDC 19 LIMITS SITE BOUNDARY Pathway Containment leakage RHR pump seal leakage Expected recirculation loop leakage Recirculation loop leakage: 1.88 gpm, with charcoal filtration, or 0.189 gpm, with no filtration TOTAL SITE BOUNDARY DOSES LPZ Pathway Containment leakage RHR pump seal leakage Expected recirculation loop leakage Recirculation loop leakage: 11.07 gpm, with charcoal filtration, or 30 OFFSITE DOSES (REM) 26 Thyroid 107.06 0.0 8.22 184.72 300.00 Thyroid 19.01 0.09 2.12 Gamma Whole Body 0.0394 0.0 0.00002 0.0006 0.0066 0.0760 5 Gamma Whole Body 3.24 0.0 0.03 0.52 Gamma Whole Body 0.293 0.0 0.003 Beta Skin 0.480 0.0 0.0014 0.0083 0.0243 0.00 30 1.11 gpm, with no filtration TOTAL LPZ DOSES 10 CFR 100 DOSE LIMITS 278.78 300.00 300 0.44 25 Enclosure PG&E Letter DCL-11-072 The proposed change revises the Post LOCA doses as seen below: CONTROL ROOM OPERATOR DOSES (REM} Gamma Beta Pathway Thyroid Whole Body Skin Containment leakage 14.05 0.042 0.51 RH R pu mp seal leakage 0.048 0.0 0.0 Expected recirculation loop leakage 1.878 0.00005 0.00038 Recirculation loop leakage: 0.42 gpm, with charcoal filtration, or 0.042 gpm, with no filtration 9.30 0.00027 0.0019 Plume radiation (egress-ingress) 4.72 0.0066 0.0243 Other direct radiation pathways 0.00 0.0760 0.00 TOTAL CONTROL ROOM OPERATOR DOSES 30.00 10 CFR 50 APPENDIX A, GDC 19 LIMITS 30 5 30 OFFSITE DOSES (REM} SITE BOUNDARY Gamma Pathway Thyroid Whole Body Containment leakage 110.0 3.26 RHR pump seal leakage 0.0 0.0 Expected recirculation loop leakage 8.22 0.03 Recirculation loop leakage: 0.42 gpm, with charcoal filtration, or 0.042 gpm, with no filtration 41.35 0.128 TOTAL SITE BOUNDARY DOSES 159.6 LPZ Gamma Pathway Thyroid Whole Body Containment leakage 20.43 0.32 RHR pump seal leakage 0.09 0.0 Expected recirculation loop leakage 2.24 0.003 Recirculation loop leakage: 0.42gpm, with charcoal filtration, or 0.042 gpm, with no filtration 11.21 0.017 TOTAL LPZ DOSES 33.97 10 CFR 100 DOSE LIMITS 300 25 The proposed amendment would provide a new process for revising input parameters in the LOCA control room operator and offsite dose analysis without requesting prior NRC approval.

Plant procedures provide administrative controls for maintaining the recirculation loop leakage below the values assumed in the 27 Enclosure PG&E Letter DCL-11-072 dose analysis in accordance with TS 5.5.2. Measured recirculation loop leakage values are lower than the flow rate limits provided in the FSARU. The proposed change would allow for the administratively controlled recirculation loop leakage to be revised to offset changes to other inputs of the control room operator and offsite dose analysis, as long as the total control room operator and offsite dose values are within the 10 CFR 50 Appendix A, GDC 19-1971 and 10 CFR 100 limits. The TS 5.5.19 Control Room Envelope Habitability Program and the TS 5.5.2 Primary Coolant Sources Outside Containment program are Technical Specification Controlled programs.

Any revisions to inputs to the LOCA control room operator and offsite doses will be made in accordance with these programs.

The requested process to revise inputs in the LOCA dose analysis is considered acceptable since the limiting thyroid dose does not exceed the applicable GDC 19-1971 and 10 CFR 100 limits. NEI 96-07 Section 4.3.3 states "For some licensees the current calculated dose consequences may already be in excess of the SRP guidelines for some events. In such cases, minimal increase is defined as less than or equal to 0.1 rem." Thus, NEI 96-07 allows a minimal increase in calculated dose consequences to be performed without prior NRC review and approval when dose consequences are in excess of SRP guidelines.

Summary In summary, the proposed revisions to the TS 3.3.5 SRs ensure the FLUR setpoint values used in SR 3.3.5.3 will protect class 1 E equipment.

For the new 230 kV degraded voltage scenario and increased ESF delays to bound the SLUR actuation time, the safety analysis results continue to meet the applicable acceptance criteria.

Inputs to the control room operator and site boundary doses are revised, but the total control room operator and offsite doses remain within the applicable 10 CFR 50 Appendix A, GDC 19-1971 and 10 CFR 100 limits. 4. REGULATORY EVALUATION 4.1 Applicable Regulatory Requirements/Criteria 10 CFR 50, Appendix A, "General Design Criteria for Nuclear Power Plants," states: "Criterion 17 --Electric power systems. An onsite electric power system and an offsite electric power system shall be provided to permit functioning of structures, systems, and components important to safety. The safety function for each system (assuming the other system is not functioning) shall be to provide sufficient capacity and capability to assure that (1) specified acceptable fuel design limits and design conditions of the reactor coolant pressure boundary are not exceeded as a result of anticipated operational 28 Enclosure PG&E Letter DCL-11-072 occurrences and (2) the core is cooled and containment integrity and other vital functions are maintained in the event of postulated accidents. "The onsite electric power supplies, including the batteries, and the onsite electric distribution system, shall have sufficient independence, redundancy, and testability to perform their safety functions assuming a single failure. "Electric power from the transmission network to the onsite electric distribution system shall be supplied by two physically independent circuits (not necessarily on separate rights of way) designed and located so as to minimize to the extent practical the likelihood of their simultaneous failure under operating and postulated accident and environmental conditions.

A switchyard common to both circuits is acceptable.

Each of these circuits shall be designed to be available in sufficient time following a loss of all onsite alternating current power supplies and the other offsite electric power circuit, to assure that specified acceptable fuel design limits and design conditions of the reactor coolant pressure boundary are not exceeded.

One of these circuits shall be designed to be available within a few seconds following a loss-of-coolant accident to assure that core cooling, containment integrity, and other vital safety functions are maintained. "Provisions shall be included to minimize the probability of losing electric power from any of the remaining supplies as a result of, or coincident with, the loss of power generated by the nuclear power unit, the loss of power from the transmission network, or the loss of power from the onsite electric power supplies. "Criterion 18--lnspection and testing of electric power systems. Electric power systems important to safety shall be designed to permit appropriate periodic inspection and testing of important areas and features, such as wiring, insulation, connections, and switchboards, to assess the continuity of the systems and the condition of their components.

The systems shall be designed with a capability to test periodically (1) the operability and functional performance of the components of the systems, such as onsite power sources, relays, switches, and buses, and (2) the operability of the systems as a whole and, under conditions as close to design as practical, the full operation sequence that brings the systems into operation, including operation of applicable portions of the protection system, and the transfer of power among the nuclear power unit, the offsite power system, and the onsite power system." 29 Enclosure PG&E Letter DCL-11-072 "Criterion 19--Control room. A control room shall be provided from which actions can be taken to operate the nuclear power unit safely under normal conditions and to maintain it in a safe condition under accident conditions, including loss-of-coolant accidents.

Adequate radiation protection shall be provided to permit access and occupancy of the control room under accident conditions without personnel receiving radiation exposures in excess of 5 rem whole body, or its equivalent to any part of the body, for the duration of the accident.

Equipment at appropriate locations outside the control room shall be provided (1) with a design capability for prompt hot shutdown of the reactor, including necessary instrumentation and controls to maintain the unit in a safe condition during hot shutdown, and (2) with a potential capability for subsequent cold shutdown of the reactor through the use of suitable procedures." 10 CFR 100.11, "Determination of exclusion area, low population zone, and population center distance," states in part: An exclusion area of such size that an individual located at any point on its boundary for two hours immediately following onset of the postulated fission product release would not receive a total radiation dose to the whole body in excess of 25 rem or a total radiation dose in excess of 300 rem to the thyroid from iodine exposure.

FSARU Section 3.1.8.3, states that DCPP conforms to 10 CFR Part 50, Appendix A, General Design Criteria 17-1971, "Electric Power Systems." FSARU Section 8.3.1.1.8.2 states that the emergency electric power system including each vital bus and its control, protection, and instrumentation is designed in accordance with IEEE Standards 308-1971 and 279-1971.

NRC Letter "Request for Additional Information

-Diablo Canyon Nuclear Power Plants, Unit 1 and 2," dated November 22, 1977 (Reference 1), defines the design and licensing requirements for sustained degraded voltage conditions at the offsite source, and for the interaction of the offsite and onsite emergency power systems. It also details first and second level undervoltage system requirements and states that: "The selection of voltage and time set points shall be determined from an analysis of the voltage requirements of the safety-related loads at a" onsite system distribution levels, the voltage protection shall include coincidence logic to preclude spurious trips of the 30 Enclosure PG&E Letter DCL-11-072 offsite power source, the allowable time delay, including margin, shall not exceed the maximum time delay that is assumed in the FSAR accident analyses, the time delay shall minimize the effect of short duration disturbances from reducing the availability of the offsite power source(s), the allowable time duration of a degraded voltage condition at all distribution system levels shall not result in failure of safety systems or components, the voltage levels at the safety-related buses should be optimized for the full load and minimum load conditions that are expected throughout the anticipated range of voltage variations of the offsite power source by appropriate adjustment of the voltage tap settings of the i nterven i ng tra nsformers." PG&E responded to this letter, with a description of how the OCPP design meets these requirements in PG&E Letter "Emergency Power System Designs for Sustained Degraded Grid Voltage Conditions," dated January 24, 1978. The 2010 NRC CDBI report (Reference

7) contained subsequent violations pertaining to this design. As stated in the purpose statement for this proposed license amendment, this LAR addresses the violations received during a CDBI. The changes proposed in this LAR meet the requirements of GOC 17-1971, GOC 18-1971, GOC 19-1971,10 CFR 100, IEEE 279-1971, and IEEE 308-1971.

4.2 Precedent None 4.3 Significant Hazards Consideration PG&E has evaluated whether or not a significant hazards consideration is involved with the proposed amendment by focusing on the three standards set forth in 10 CFR 50.92, "Issuance of amendment," as discussed below: (1) Ooes the proposed change involve a significant increase in the probability or consequences of an accident previously evaluated?

Response:

No. The diesel generators (DGs) provide a source of emergency power when offsite power is either unavailable, or is degraded below a point that would allow safe unit operation.

Undervoltage protection will generate a loss of power (LOP) OG start if a loss of voltage or degraded voltage condition 31 Enclosure PG&E Letter DCL-11-072 occurs on the 4.16 kV vital bus. The proposed technical specification (TS) change affects the voltage at which an emergency bus that is experiencing sustained degraded voltage will disconnect from offsite power and transfer to the DGs. While the TS limits are revised, the function remains the same and will continue to be performed.

The first level undervoltage relays (FLUR) and second level undervoltage relays (SLUR) will continue to meet their required function to transfer 4.16 kV buses to the DGs in the event of insufficient offsite power voltage. This transfer will ensure that the class 1 E equipment is capable of performing its function to meet the requirements of the accident analysis.

The revised TS surveillance requirement (SR) 3.3.5.3 setpoints will not cause unnecessary separation of engineered safety function (ESF) loads from the 230 kV System. The proposed change does not affect any accident initiators or precursors.

The ESF function delay times are bounding input parameters that represent actual plant performance for when these ESF functions can be credited to begin operating after an accident has already occurred.

The increased ESF delay times are not physically related to the cause of any accident.

Therefore, the increase in ESF delay times do not introduce the possibility of a change in the frequency of an accident previously evaluated.

The revised LOCA control room operator and offsite dose analysis results remain within the applicable GDC 19-1971 and 10 CFR 100 limits. Therefore, the proposed activity does not result in an increase in the consequence of an accident previously evaluated in the FSARU. Therefore, the probability or consequences of any accident previously evaluated will not be significantly increased as a result of the proposed change. (2) Does the proposed change create the possibility of a new or different accident from any accident previously evaluated?

Response:

No. No new accident scenarios, transient precursors, failure mechanisms, or limiting single failures are introduced as a result of the proposed change. The revised surveillance requirements will continue to assure equipment reliability such that plant safety is maintained or will be enhanced.

An increased ESF delay time is not an initiator of any accident and does not create any new system interactions or failure modes of any structures, systems or components (SSC). Equipment important to safety will continue to operate as designed.

The changes do not result in adverse conditions or result in any increase in the challenges to safety systems. Therefore, operation of the Diablo Canyon 32 Enclosure PG&E Letter DCL-11-072 Power Plant in accordance with the proposed amendment will not create the possibility of a new or different type of accident from any accident previously evaluated.

Therefore, the proposed change does not create the possibility of a new or different accident from any accident previously evaluated.

(3) Does the proposed change involve a significant reduction in a margin of safety? Response:

No. The DGs provide emergency electrical power to the safeguard buses in support of equipment required to mitigate the consequences of design basis accidents and anticipated operational occurrences, including an assumed loss of all offsite power. SR 3.3.5.3 verifies that the LOP DG start instrumentation channels respond to measured parameters within the necessary range and accuracy.

The proposed amendment corrects nonconservative values in the TS limits for the degraded voltage protection function.

The proposed change to this SR assures that design requirements of the emergency electrical power system continue to be met. There are no new or significant changes to the initial conditions contributing to accident severity or consequences.

The proposed increase in ESF delay times is considered an analysis input change. However, the safety analyses continue to meet all applicable acceptance criteria.

The proposed amendment will not otherwise affect the plant protective boundaries, will not cause a release of fission products to the public, nor will it degrade the performance of any other SSCs important to safety. Therefore, the proposed change does not involve a significant reduction in a margin of safety. Based on the above evaluation, PG&E concludes that the proposed change does not involve a significant hazards consideration under the standards set forth in 10 CFR 50.92(c), and accordingly, a finding of "no significant hazards consideration" is justified.

4.4 Conclusions In conclusion, based on the considerations discussed above, (1) there is reasonable assurance that the health and safety of the public will not be endangered by operation in the proposed manner, (2) such activities will be conducted in compliance with the Commission's regulations, and (3) 33 Enclosure PG&E Letter DCL 072 the issuance of the amendment will not be inimical to the common defense and security or to the health and safety of the public. 5. ENVIRONMENTAL CONSIDERATION PG&E has evaluated the proposed amendment and has determined that the proposed amendment does not involve (i) a significant hazards consideration, (ii) a significant change in the types or significant increase in the amounts of any effluents that may be released offsite, or (iii) a significant increase in individual or cumulative occupational radiation exposure.

Accordingly, the proposed amendment meets the eligibility criterion for categorical exclusion set forth in 10 CFR 51.22(c)(9).

Therefore, pursuant to 10 CFR 51.22(b), no environmental impact statement or environmental assessment needs to be prepared in connection with the proposed amendment.

6. REFERENCES
1. NRC Letter "Request for Additional Information

-Diablo Canyon Nuclear Power Plants, Unit 1 and 2," dated November 22, 1977 2. PG&E Letter "Emergency Power System Designs for Sustained Degraded Grid Voltage Conditions," dated January 24, 1978 3. PG&E Licensee Event Report 1-2010-002-02, "Potential Loss of Safety-Related Pumps due to Degraded Voltage During Postulated Accidents," dated September 24, 2010 4. NUREG-1102, Revision 0, "Technical Specifications Diablo Canyon Power Plant, Unit No.1," dated November 1984 5. NUREG-1132, Revision 0, "Technical Specifications Diablo Canyon Power Plant, Unit No.2," dated April 1985 6. PG&E Calculation No. 9000041128 (357S-DC), Revision 2, "4.16 kV Bus FLUR & SLUR Setpoint Calculation," dated July 18, 2011 7. NRC Letter "Diablo Canyon Power Plant -NRC Component Design Bases Inspection Report 05000275/2010007 and 05000323/2010007," dated July 23, 2010 8. PG&E Calculation No.9000008518 (170-DC), Revision 16A, "4kV Class 1 E Motor Overcurrent Relay Setpoints-Basler Electric," dated May 5,2011 9. PG&E Calculation No. 9000033535 (359-DC), Revision 9A, "Determination of 230 kV Grid Capability Limits As DCPP Offsite Power Source," dated May 6,2011 10. Westinghouse Electric LLC Letter PGE-1 0-54, Revision 1, "Pacific Gas & Electric Company, Diablo Canyon Units 1 & 2, 230 kV Degraded 34 Enclosure PG&E Letter DCL-11-072 Voltage Evaluation

-Engineering Report," dated October 15, 2010 (proprietary)

11. License Amendment No. 37 to Facility Operating License No. DPR-80 and Amendment No. 36 to Facility Operating License No. DPR-82, "Issuance of Amendments (TAC NOS. 71387 and 71388)," dated May 10, 1989 12. License Amendment No. 191 to Facility Operating License No. DPR-80, "Diablo Canyon Power Plant, Unit No. 1 -Issuance of Amendment RE: Technical Specification 5.6.5, 'Core Operating Limits Report (COLR),(TAC NO. MC9299)," dated November 21,2006 13. License Amendment No. 192 to Facility Operating License No. DPR-82, "Diablo Canyon Power Plant, Unit No.2 -Issuance of Amendment RE: TS 5.6.5, 'Core Operating Limits Report (COLR)," (TAC NO. MC9567),'

dated December 20, 2006 14. Safety Evaluation by the Directorate of Licensing U.S. Atomic Energy Commission in the Matter of Pacific Gas and Electric Company Diablo Canyon Nuclear Power Station, Units 1 and 2 San Luis Obispo County, California Docket Nos. 50-275 and 50-323, dated October 16, 1974 15. License Amendment No. 80 to Facility Operating License No. DPR-80 and Amendment No. 79 to Facility Operating License No. DPR-82, "Issuance of Amendments for Diablo Canyon Nuclear Power Plant, Unit No.1 (TAC No. M79425) and Unit No. (TAC No. M79426)," dated April 1, 1993. 16. PG&E Letter DCL-02-049, "10 CFR 50.59 Report of Changes, Tests, and Experiments for the Period January 1, 2000, through December 31,2001," dated April 6, 2002. 35 Enclosure Attachment 1 PG&E Letter DCL-11-072 Proposed Technical Specification Changes (marked-up)

LOP DG Start Instrumentation 3.3.5 S URV E ILLANC E R E QUIR E M E NTS (continued)

SR 3.3.5.3 S URV E IL L AN CE Perform CHANNEL CALIBRATION with Allowable Value setpoints as follows: a. Loss of voltage Diesel Start Allowable Value 0 V with a time delay of S 0.8 seconds and 2583 V with a S 10 second time delay. 4--wGoods-aoo

b. Degraded voltage Diesel Start Allowable Value 3785 V with a time delay of s 10 seconds. Degraded voltage initiation of Load Shed Allowable Value 3785 V with a time delay of s 20 seconds. FREQ U E N C Y In accordance with the Surveillance Frequency Control Program Loss of yoltage initiation of load shed with relay Allowable Values of: 3328 V for s 10 sec 3120 V for s 6 sec 2704 V for s 4 sec And one relay Allowable Value of: j 3411 V, instantaneous

.........,'-/..........,"---

...... '--' .....

DIABLO CANYON -UNITS 1 & 2 3.3-42 Unit 1 -Amendment No. Unit 2 -Amendment No.

Enclosure Attachment 2 PG&E Letter DCL-11-072 Proposed Technical Specification Changes (retyped)

Remove Page Insert Page 3.3-42 3.3-42 LOP DG Start Instrumentation 3.3.5 SURVEILLANCE REQUIREMENTS (continued)

SR 3.3.5.3 SURVEILLANCE Perform CHANNEL CALIBRATION with Allowable Value setpoints as follows: a. Loss of voltage Diesel Start Allowable Value 0 V with a time delay of:::;; 0.8 seconds and 2583 V with a :::;; 10 second time delay. Loss of voltage initiation of load shed with relay Allowable Values of: ;;:::3328 V for ::;10 sec ;;:::3120 V for ::;6 sec ;;:::2704 V for ::;4 sec And one relay Allowable Value of: ;;:::3411 V, instantaneous

b. Degraded voltage Diesel Start Allowable Value 3785 V with a time delay of :::;; 10 seconds. Degraded voltage initiation of Load Shed Allowable Value 3785 V with a time delay of :::;; 20 seconds. FREQUENCY I n accordance with the Surveillance Frequency Control Program DIABLO CANYON -UNITS 1 & 2 3.3-42 Unit 1 -Amendment No.

Unit 2 -Amendment No.

Enclosure Attachment 3 PG&E Letter DCL-11-072 Changes to Technical Specification Bases Pages (For information only)

LOP DG Start Instrumentation B 3.3.5 B 3.3 INSTRUMENTATION B 3.3.5 Loss of Power (LOP) Diesel Generator (DG) Start Instrumentation BASES BACKGROUND The DGs provide a source of emergency power when offsite power is either unavailable or is degraded below a point that would allow safe unit operation.

Undervoltage protection will generate an LOP start if a loss of voltage or degraded voltage condition occurs on the 4.16kV vital bus. There are three LOP start signals, one for each 4.16 kV vital bus. Three u U ndervoltage relays are provided on each 4.16 kV 44-eQ Class 1E vital bus for detecting sustained degraded voltage condition or a loss of bus voltage. A relay Relays will generate an LOP signal (first level undervoltage type relay setpoint) if the voltage is below +a%equipmen t protection thresholds for a short time. The DG start relays (one per bus) have an inverse time characteristic and will generate an LOP signal with a Allowable Values of? 0 vol ts with a time delay of =::; 0.8 sec onds tfme delay at > 0 volts and? 2583 v o l ts with at a=::;1 0 second s time 2583 volts. In addition, the circuit breakers for all loads, except the 4160-480 V load center transformers, are opened automatically by Load Shedding Relays for first level undervoltage.

Each of the vital 4.16 kV 4160 kV buses has a separate f*lli-two channel set of these relays. The relay channel s have a two-out-of-two logic arrangement for each bus to prevent inadvertent tripping of operating loads during a loss of voltage either from a single failure in the potential circuits or from human error. One relay tfips channe l cont a in s one relay with an Allowable Valu e o f instantaneously at >

volts , i nstantaneous. The second of the two channe l s consists of 3 discrete v oltage and time delay relays , with A ll owab l e Values of? 3328 vol ts for =::; 10 seconds, ? 3 1 2 0 volts fo r seconds , and? 2704 for =::; 4 seconds , respectively , has an inverse time characteristic and delay of < 4 seconds at no voltage and a < 25 second delay v{ith > 2583 volts to prevent loss of operating loads during transient voltage dips, and to permit the offsite power sources to pick up the load. The LOP start actuation is described in FSAR, Section 8.3 (Ref. 1). Should there be a degraded voltage condition (second level undervoltage), where the voltage of the vital 44-00-4. 16 kV buses remains at approximately 3785 k¥-volt s or below, but above the setpoints of the first level undervoltage relays, the following second level undervoltage actions occur automatically:

(1) After a=::;1 0 second time delay, the respective diesel generators will start. (2) After a =::; 20 second time delay, if the undervoltage condition persists, the circuit breakers for all loads to the respective vital 4160 kV buses, except the 4160-480 V load center transformer, are opened and sequentially loaded on the DG. ( continued)

DIABLO CANYON -UNITS 1 & 2 Rev TBD Page 1 of 5 BASES BACKGROUND ( continued)

APPLICABLE SAFETY ANALYSES LOP DG Start Instrumentation B 3.3.5 Each vital 44-eG-4. 16 kV bus has two second level undervoltage relays operating with a two-out-of-two logic. Each vital 4160kV Bus also has two second level undervoltage timers. One timer provides the Diesel Generator start and the other will initiate load shedding.

Allowable Value Setpoints The Setpoints used in the relays are based on the analytical limits presented in FSft.R, Chapter 15 (Ref. 2). The vo lta g e and t i me de l ay setpoints prote c t ESF equ i pment. The a ll o w a bl e ti me de l a y , i nc lu d i ng marg i n , s hall n ot e x ceed the max i mum tim e d e l a y ass u med i n th e FSAR U a cciden t ana l ys i s (C h apters 6 a nd 1 5) The selection of these Setpoints is such that adequate protection is provided when all sensor and processing time delays are taken into account. The actual nominal Setpoint entered into the relays is normally still more conservative than that required by the Allowable Value. If the measured setpoint does not exceed the Allowable Value, the undervoltage relay is considered OPERABLE.

If the measured time delay does not exceed the Allowable Value, the timer is considered OPERABLE.

Setpoints adjusted in accordance with the Allowable Value ensure that the consequences of accidents will be acceptable, providing the unit is operated from within the LCOs at the onset of the accident and that the equipment functions as designed.

Allowable Values are specified for each Function in the LCO. The nominal setpoints are selected to ensure that the setpoint measured by the surveillance procedure does not exceed the Allowable Value if the undervoltage relay is performing as required.

If the measured setpoint does not exceed the Allowable Value, the undervoltage relay is considered OPERABLE.

Operation with a Setpoint less conservative than the nominal Setpoint, but within the Allowable Value, is acceptable provided that operation and testing is consistent with the assumptions of the unit specific setpoint calculation.

Each Allowable Value specified is more conservative than the analytical limit assumed in the transient and accident analyses in order to account for instrument uncertainties appropriate to the trip function.

These uncertainties are defined in calculation s 174ft. DC Rev. 0 (Ref. 4) and Rev. 0 (Ref. a 4). The LOP DG start instrumentation is required for the Engineered Safety Features (ESF) Systems to function in any accident with a loss of offsite power. Its design basis is that of the ESF Actuation System (ESFAS). ( continued)

DIABLO CANYON -UNITS 1 & 2 Rev TBD Page 2 of 5 BASES APPLICABLE SAFETY ANALYSES ( continued)

LCO LOP DG Start Instrumentation B 3.3.5 Accident analyses credit the loading of the DG based on the loss of offsite power during a loss of coolant accident (LOCA). The actual DG start has historically been associated with the ESFAS actuation.

The DG loading has been included in the delay time associated with each safety system component requiring DG supplied power following a loss of offsite power. The analyses assume a non-mechanistic DG loading, which does not explicitly account for each individual component of loss of power detection and subsequent actions. The required channels of LOP DG start instrumentation, in conjunction with the ESF systems powered from the DGs, provide unit protection in the event of any of the analyzed accidents discussed in Reference 2, in which a loss of offsite power is assumed. The delay times assumed in the safety analysis for the ESF equipment include the 10 second DG start delay, and the appropriate sequencing delay, if applicable.

The response times for ESFAS actuated equipment in LCO 3.3.2, "Engineered Safety Feature Actuation System (ESFAS) Instrumentation," include the appropriate DG loading and sequencing delay. The LOP DG start instrumentation channels satisfy Criterion 3 of 10 CFR 50.36( c)(2)(ii).

The LCO for LOP DG start instrumentation requires that one channel per bus for loss of voltage DG start with, two channels per bus for initiation of load shed and their two corresponding timers and two channels per bus of degraded voltage function with one timer per bus for DG start and one timer per bus for initiation of load shed Functions shall be OPERABLE in MODES 1, 2, 3, and 4 when the LOP DG start instrumentation supports safety systems associated with the ESFAS. In MODES 5 and 6, the channels must be OPERABLE whenever the associated DG is required to be OPERABLE to ensure that the automatic start of the DG is available when needed. Loss of the LOP DG Start I nstrumentation Function could result in the delay of safety systems initiation when required.

This could lead to unacceptable consequences during accidents.

During the loss of offsite power the DG powers the motor driven auxiliary feedwater pumps. Failure of these pumps to start would leave only one turbine driven pump, as well as an increased potential for a loss of decay heat removal through the secondary system. ( continued)

DIABLO CANYON -UNITS 1 & 2 Rev TBD Page 3 of 5 BASES (continued)

APPLICABILITY ACTIONS SURVEILLANCE REQUIREMENTS LOP DG Start Instrumentation B 3.3.5 The LOP DG Start Instrumentation Functions are required in MODES 1, 2, 3, and 4 because ESF Functions are designed to provide protection in these MODES. Actuation in MODE 5 or 6 is required whenever the required DG must be OPERABLE so that it can perform its function on an LOP or degraded power to the vital bus. In the event a channel's Setpoint is found nonconservative with respect to the Allowable Value, or the channel is found inoperable, then the function that channel provides must be declared inoperable and the LCO Condition entered for the particular protection function affected.

Because the required channels are specified on a per bus basis, the Condition may be entered separately for each bus as appropriate.

A Note has been added in the ACTIONS to clarify the application of Completion Time rules. The Conditions of this Specification may be entered independently for each Function listed in the LCO. The Completion Time(s) of the inoperable channel(s) of a Function will be tracked separately for each Function starting from the time the Condition was entered for that Function.

A.1 Condition A applies when one or more of the loss of voltage or the degraded voltage channel functions (this includes both relays and timers) on a single bus are inoperable.

In these circumstances the Conditions specified in LCO 3.8.1, "AC Sources-Operating," or LCO 3.8.2, "AC Sources-Shutdown," for the DG made inoperable by failure of the LOP instrumentation are required to be entered immediately.

The actions of those LCOs provide for adequate compensatory actions to assure unit safety. A Note is added to allow bypassing one channel for up to 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> for surveillance testing. This allowance is made where bypassing the channel does not cause an actuation and where at least one other channel is monitoring that parameter.

SR 3.3.5.1 not used SR 3.3.5.2 SR 3.3.5.2 is the performance of a TADOT. The test checks trip devices that provide actuation signals directly, bypassing the analog process control equipment.

For these tests, the relay Setpoints are verified and adjusted as necessary.

Plant procedures verify that the instrument channel functions as required by verifying the as-left and as-found settings are consistent with those established by the setpoint methodology. The Surveillance Frequency is based on operating experience, equipment reliability, and plant risk and is controlled under the Surveillance Frequency Control Program. ( continued)

DIABLO CANYON -UNITS 1 & 2 Rev TBD Page 4 of 5 BASES SURVEILLANCE REQUIREMENTS ( continued)

REFERENCES SR 3.3.5.3 LOP DG Start Instrumentation B 3.3.5 SR 3.3.5.3 is the performance of a CHANNEL CALIBRATION.

The setpoints, as well as the response to a loss of voltage and a degraded voltage test, shall include a single point verification that the trip occurs within the required time delay. CHANNEL CALIBRATION is a complete check of the instrument loop, including the sensor. The test verifies that the channel responds to a measured parameter within the necessary range and accuracy.

Plant procedures verify that the i nstrum ent channel functions as requ ired by verifying the as-l eft and as-found s ett ings are consistent with those estab lis hed by the setpoint metho dology. The Surveillance Frequency is based on operating experience, equipment reliability, and plant risk and is controlled under the Surveillance Frequency Control Program. 1. FSAR, Section 8.3. 2. FSAR, Chapter 15. 3. Chapter 6. 4. Calculation 359S-DC, "4.1 6 kV Bus FLUR & SLUR Setpoint Ca l cu l ation. " 174,1\ DC, "Undervoltage Relay Settings for 4 KV System (27HFB2 & 27HFT1 )." 5. Calculation 357P DC, "SLUR and SLUR Timer Setpoints." DIABLO CANYON -UNITS 1 & 2 Rev TBD Page 5 of 5 FSARU Markups Enclosure Attachment 4 PG&E Letter DCL-11-072 DCPP UNIT S 1 & 2 FSAR UPDAT E (2) I f the c ompon e nt is s h a r e d with o th e r s y s t e m s , it i s a lign e d during norm a l pl a nt o p e r a tion to p e rform its a ccident function, o r, if not a lign e d t o it s accident function, two valves in parallel are provided to align the system fo r inje c tion, a nd two v a lve s in s eries a r e provided to i s olate portion s of t he s y stem not utili zed fo r inj ec ti on. These v a lv es a r e a ut o m a ti ca lly actuated by the safety injection signal. Table 6.3-8 indicates the alignment of components during normal operation, and the realignment required to perform the accident function. 6.3.3.6.1 Dependence on Other Systems Other systems that operate in conjunction with the ECCS are as follows: (1) The CCW system (Section 9.2.2) cools the RH R heat exchangers during the recirculation mode of operation.

It also supplies cooling water to CCP1 and CCP2, the safety injection pumps, and the RHR pumps during the injection and recirculation modes of operation.

(2) The ASW system (Section 9.2.1) provides cooling water to the CCW heat exchangers.

(3) The electrical systems (Section 8.3) provide normal and emergency power sources for the ECCSs. (4) The ESF actuation system (ESFAS) (Section 7.3) generates the initiation signal for emergency core cooling. (5) The AFW system (Section 6.5) supplies feedwater to the steam generators.

(6) The auxiliary building ventilation system (Section 9.4) removes heat from the pump compartments and provides for radioactivity contamination control should some leakage occur in a compartment.

6.3.3.7 Lag Times The sequence and time-delays for actuation of ECCS components for the injection and recirculation phases of emergency core cooling are given in Table 6.3-7. The ECCS delay ti mes assumed i n the accident analyses bound these values. Alignment of the major ECCS components during the injection and recirculation phases is shown in Figures 6.3-4 and 6.3-5, respectively.

The sequence of eve nts tables in Chapter 15 Tables 15.3 2 and 15.3 3 summarize the calculated times at which the major components perform the safety-related functions for those various accident conditions (tabulated in Table 15.1-2:4) that require the ECCS. 6.3-26 Revision 19 May 2010 DCPP UNITS 1 & 2 FSAR UPDAT E Th e minimum activ e compon e nt s will be c a p a bl e of d e liv e ring full r a t e d flow within a s p e cifi e d tim e int e rv a l a ft e r pro cess p a r a m e t e r s r ea ch th e se tpoint s f o r th e sa f e ty injection signal. Response of the system is automatic with appropriate allowances for delays in actuation of circuitry and a ctive components.

T h e ac tiv e portion s of the s y s t em are ac tu a t e d b y th e safety i n j e ction s ign a l. In a n a ly ses of s y s t e m pe rf o rm a n ce , delays in reaching the programmed trip points and in actuation of components are established on the basis that only emergency onsite power is available.

The starting sequence following a loss of offsite power is discussed in detail in Chapter 8. For acc i de nt s that a s sum e a L OOP , +t he ECCS is operational after an elapsed time not greater than 25 seconds after th e S I s i gna l i s ac tu a t e d , including the time to bring the RHR pumps up to full speed. T h e EGGS ope r a ti o n has a l so b een e v a lu ated in P GE-10-54 (Refere n ce 16) f o r a n in creased de l ay t i me of 42 s eco nd s i n order to bo und pot e nti a l sce n ar i os i n which th e m a xi m um S LU R actua tion time o c cur s. The starting times for components of the ECCS are consistent with the delay times used in the LOCA analyses for large and small breaks. In the LOCA analysis presented in Sections 15.3 and 15.4, no credit is assumed for partial flow prior to the establishment of full flow b ased o n a ll EGGS pumps ac hi e ving rated speed and no credit is assumed for the availability of normal 230-kV and 500-kV offsite power sources. Th e PG E-10-54 (Refere nc e 16) e v a l uat i o n whi ch b o und s th e ma xi mum SL U R actu a tion ti me , a l so assumes no c re d i t f or part i a l EGGS fl o w until a ll EGGS pumps h a v e ob t ai ned r ated speed and ac hi e ve d f u ll f lo w capab ilit y. For smaller LOCAs, there can b e is some additional delay before the process variables reach their respective programmed trip setpoints since this is a function of the severity of the transient imposed by the accident.

This is allowed for in the analyses of the range of LOCAs. Accumulator injection occurs immediately when RCS pressure has decreased below the operating pressure of the accumulator.

6.3.3.8 Limits on System P arameters The specification of individual parameters as indicated in Table 6.3-1 includes due consideration of allowances for margin over and above the required performance value (e.g., pump flow and NPSH), and the most severe conditions to which the component could be subjected (e.g., pressure, temperature, and flow). This consideration ensures that the ECCS is capable of meeting its minimum required level of functional performance.

6.3.3.8.1 Coolant Storage Reserves A minimum RWST volume is provided to ensure that, after an RCS break, sufficient water is injected and available within containment to permit recirculation cooling flow to 6.3-27 Revision 19 May 2010 DCPP UNITS 1 & 2 FSAR UPDATE 2. Westinghouse ECCS -Plant Sensitivity Studies, WCAP-8340 (Proprietary) and WCAP-8356, July 1974. 3. Westinghouse ECCS Evaluation Model-Summary, WCAP-8339, July 1974. 4. Westinghouse ECCS Evaluation Model -Supplementary Information, WCAP-8471 (Proprietary) and WCAP-8472, January 1975. 5. Westinghouse ECCS Evaluation Model -October 1975 Version, WCAP-8622 (Proprietary) and WCAP-8623, November 1975. 6. Environmental Testing of Engineered Safety Features Related Equipment (NSSS-Standard Scope), WCAP-7744, Volume I, August 1971. 7. Westinghouse ECCS Evaluation Model-February 1978 Version, WCAP-9220 (Proprietary) and WCAP-9221, February 1978. 8. "Reliability, Stress and Failure Rate Data for Electronic Equipment," Military Standardization Handbook, M I L-H DBK-217 A, December 1965, Department of Defense, Washington, D.C. 9. Diablo Canyon Power Plant -Inservice Inspection Program Plan -The Third 10 Year Inspection Interval.

10. Technical Specifications, Diablo Canyon Power Plant Units 1 and 2, Appendix A to License Nos. DPR-80 and DPR-82, as amended. 11. Regulatory Guide 1.79, Preoperational Testing of Emergency Core Cooling System for Pressurized Water Reactors, USNRC, June 1974. 12. IEEE-Std-279, Criteria for Protection Systems for Nuclear Power Generating Stations, 1971. 13. Westinghouse ECCS Evaluation Model, 1981 Version, WCAP-9220-P-A, Rev. 7 (proprietary), WCPA-9221-A, Rev. 1 (nonproprietary), February 1982. 14. Young, M. Y., et aI., BART-A1: A Computer Code for the Best Estimate Analysis of REFLOOD Transients, WCAP-9561-P, Addendum 3, June 1986. 15. Chiou, J. S., et aI., Models for PWR Reflood Calculations Using the BART Code, WCAP-10062.
16. W est i nghouse l etter PGE-10-54, D i ab l o Canyon 230 k V De gr a d ed V o l tage E v a l uat i on -Eng i neer i ng Re port Re vi s i on 1 , October 15 , 2 010. 6.3-36 Revision 19 May 2010 DCPP UNITS 1 & 2 FSAR UPDATE TABLE 6.3-7 Sheet 1 of 4 SEQUENCE AND DELAY TIMES FOR STARTUP OF ECCS Delay, sec References Action Sequence Actuation

-(Subsystem or Minimum ECCS Performance Section -Accident Signal(s)

Comgonent}

!bl ill ill Design Performance Assumed in Analysis FSAR Figures Tables 1. Major Reactor 15.4.1 Coolant System Rupture (LOCA) a. Injection phase (g) Accumulator tank (g) (g) (g) 4 tanks, each with 850 fe of Three tanks injecting into RCS; 6.3 8.3-4 borated water @ 600 psig one injecting into broken loop (a) Containment 10 Double barrier; fast automatic A single active failure is 6.2.4 6.2-12, 8.3-4 isolation valves valve closure upon receipt of CIS allowable 6.2-13 & 6.2-14 (b) (d) ECCS required (k) (k) See Rapid reliable system alignment or A single active failure is 6.3.2 7.3-22, 8.3-4 valves Table isolation allowable 7.3-33 6.3-1 (b) (d) Centrifugal

-5 15 4-1/2 Two centrifugal charging pumps One pump required at 6.3.2, 7.3-4 8.3-4 charging pumps supply borated water into a single design flow 9.3.4 injection flowpath splitting into 4 cold leg injection lines (b) (d) Safety injection Two pumps inject via a single path One pump delivering at 6.3.2 3.2-9 pumps splitting into 4 cold leg injection design flow lines (b) (d) Residual heat Two pumps inject into 4 cold legs, One pump delivering at 6.3.2, 3.2-9 removal pumps via 2 lines that each split into 2 design flow 5.5.6 cold leg injection lines (b) (d) Component cooling 25/25 35/35/ 4-112 Two flowpaths; each 11,500 gpm One flowpath required at 9.2.2 7.3-7 8.3-4 water pumps /30 40 @ 130 ft design flow (e) Auxiliary feed-30/35 40/45 5 Two flowpaths; each 800 gpm One flowpath required at 6.5.2 7.3-8 8.3-4 water pumps @2350ft design flow (b) (d) Auxiliary salt-30/35 40/45 5 Two flowpaths; each 11,000 gpm One flowpath required at 9.2.7 7.3-5 8.3-4 water pumps @115ft design flow Revision 12 September 1998 Accident b. Recirculation phase 2. Major Seccondary System Rupture Actuation_

Signa((s) (c) (t) (b) DCPP UNITS 1 & 2 FSAR UPDATE Action Sequence (Subsystem or Comoonent)

Containment spray pumps Pump 1 Pump 2 Operating personnel shift system alignment from injection phase Delav. sec i!Jl .ill .ill 26 26 1.7 22 22 1.7 (Total switchover time is approximately 10 min. See 6.3.2) Action sequence Same as 1 a above similar to 1a above. Operation of ESF required.

Valves isolate feedwater

& steam TABLE 6.3-7 Design Performance Two f1owpaths; each 2600 gpm @450ft (Design performance for ECCSA and related equipment as described in 1a above) Same as 1 a above Sheet 2 of 4 References Minimum ECCS Performance Section -Assumed in Analysis FSAR Figures Tables One f10wpath required at 7.3-11 8.3-4 design flow A single failure is allowable 6.3.2 Same as 1 a above with these 15.4.2 further notes: Accumulator and low head injection required only in the severe cases. Since no RCS rupture has occurred, all four accumu-ators are functional Revision 12 September 1998 DCPP UNITS 1 & 2 FSAR UPDATE TABLE 6.3-7 Sheet 3 of 4 Action Sequence Actuation_ (Subsystem or Minimum ECCS Performance Section -Accident Signal(s)

Component) .U:ll ill. ill Design Performance Assumed in Analysis FSAR Figures Tables 3. Steam Generator Low Same as 1a Same as 1 a above with Same as 1 a above Same as 1 a above (but all four 15.4.3 Tube Rupture pressurizer above although no additional isolation done accumulators assumed pressure containment within 30 minutes functional).

Conservative spray. estimate of 125,000 Ib of Additionally, reactor coolant transferred to automatic isolation the secondary side of the of individual steam affected steam generator generator blowdown valve occurs due to SGSD liquid radiation monitor. Injection and charging flow regulated to maintain visible pressurizer water level. Auxiliary feedwater to affected SG manually isolated.

Pressurizer reliefs operated to reduce RCS pressure under 1000 psia 4. Minor RCS Low 15.3.1 Rupture which pressurizer Actuates ECCS pressure, or level, or high containmen t pressure a. Injection phase Same as Same as 1a Same as 1 a above Same as 1 a above Same as 1 a above 1a above above

b. Recirculation Same as Same as 1a Same as 1 a above Same as 1 a above Same as 1 a above 1a above above Revision 12 September 1998 DCPP UNITS 1 & 2 FSAR UPDATE TABLE 6.3-7 Sheet 4 of 4 (a) Initiated by means of containment isolation signal, which occurs on containment high pressure (2 of 3) or on safety injection signal (SIS). (b) Safety injection signal actuates on any of the following:

Low pressurizer pressure , high containment pressure, low steamline pressure , or manual actuation. (c) Containment spray actuation signal, which occurs on containment high-high pressure (2 of 4), or manual actuation. (d) Emergency diesel loading sequencer loads the diesel in accordance with the sequence shown in Tables 8.3-2 and 8.3-4. Also see Figures 8.3-9,8.3-10,8.3-11, and 8.3-1 6. (e) Auxiliary feedwater autostart signal, which occurs with a SIS., SG low-low level or tripp i ng of both main feedwater pumps. (f) Water level indication and alarms on the refueling water storage tank and in the containment sump provide ample warning to terminate the injection mode and begin the r ec i rcula ti o n mode whil e the operating pumps still have adequate net positive suction head. Manual switch over by operating personnel changes the ECCS from injection to recirculation mode. (g) All valves between the accumulators and the RCS are required to be open in Modes 1 , 2, and 3; consequently, the accumulators inject as soon as the RCS pressure fjro p s below the p r ess ur e (600 psia) of the accumulators. (h) Electrical and instrumentation delay time after "S" signa l with main generator power or offsite power available.

For containment spray pumps, delay time is after u P" si bn a l. (i) Electrical and instrumentation delay time after "S" signa l using diesel generator for a LOOP. For containment spray pumps, delay time is after u P" signal. Addit ion al ct/ay times t o b ou n d th e ma x im u m 4 kV SLUR actuation time are documented in PGE-10-S 4 (Re f erence 1 6). 0) Equipment startup time after receipt of signal. (k) These delay times vary. Revisioh 1 2 Se ptemb e r 199 8 DCPP UNITS 1 & 2 FSAR UPDATE A minimum of two CFCUs are available and a maximum of three CFCUs are assumed to be available based on the single failure assumptions.

Three long term cases are analyzed to assess the effects of single failures.

The first case assumes minimum safeguards based on the postulated single failure of an SSPS train. This assumption results in the loss-of-one train of safeguards equipment.

The operating equipment is conservatively modeled as: two CFCUs, one containment spray pump, one train of RHR, and one CCW heat exchanger. The other two cases assume maximum safeguards, in which both trains of SSPS are available.

With the maximum safeguards cases, the single failure assumptions are the failure of one containment spray pump or the failure of one CFCU. The analysis of these three cases provides confidence that the effect of credible single failures is bounded. The fan coolers in the containment evaluation model are modeled to actuate on the containment high pressure setpoint with uncertainty biased high, (5 psig), and begin removing heat from containment after a 4B-second delay with a LOOP. PGE-10-54 (R eference 20) evaluated an i ncreased CFCU LOOP de l ay t ime o f 52 seconds to bound th e m ax imum 4 kV SLUR actuat ion tim e. This evaluat i on was petiorm ed only for the limiting Unit 2 cases to assess the impa ct on the peak conta inment pressure and temp erat ur e. The CFCUs are cooled by CCW. The heat removal rate per containment fan cooler is calculated as a function of containment steam saturation temperature, the CCW inlet temperature and flow rate, and input to the GOTHIC cooler model. The heat removal rate is multiplied by the number of CFCUs available.

The heat removed from the containment control volume is transferred to the CCW control volume receiving the flow through the CFCUs using a coupled heater model. Containment Spray System The containment spray is modeled with a boundary condition.

DCPP has two trains of containment safeguards available, with one spray pump per train. An inherent assumption in the LOCA containment analysis is that offsite power is lost with the pipe rupture. This results in the actuation of the three EDGs powering the two trains of safeguards equipment.

Startup of the EDGs delays the operation of the safeguards equipment that is required to mitigate the transient.

Relative to the single failure criterion with respect to a LOCA event, one spray pump is considered inoperable due to the SSPS failure (minimum safeguards case) or as a single failure in a maximum safeguards case. In the maximum safeguards case, in which the single failure is assumed to be one CFCU, two spray pumps are available. The containment spray actuation is modeled on the containment high-high pressure setpoint with uncertainty biased high (24.7 psig). The sprays begin injecting gO°F water after a specified BO second delay. The spray flow rate is a function of containment pressure and is presented in Table 6.2D-1B. The containment spray is credited only 6.20-29 Revision 18 October 2008 OCPP UNITS 1 & 2 FSAR UPDATE during the injection phase of the transient and is terminated on a refueling water storage tank empty alarm after switchover to cold leg recirculation at a time based on the number of Sl and spray pumps operating.

The timing of recirculation and spray termination assumed in the LOCA containment analysis are presented in Table 6.20-17. PGE-10-S4 (Refere nce 20) eva l uated an increased containment spray LOOP delay tim e of 100 seconds to bound the maximum 4 kV SLUR actuation time. Th i s evaluat ion w as performed only for the limitin g Unit 2 cases to assess th e i mpact on the peak containment press ure and temperature. Accumulator Nitrogen Gas Modeling The accumulator nitrogen gas release is modeled with a flow boundary condition in the LOCA containment model. The nitrogen release rate was conservatively calculated by maximizing the mass available to be injected.

The nitrogen gas release rate was used as input for the GOTHIC function, as a specified rate over a fixed time period. Nitrogen gas was released to the containment at a rate of 327.4 lbm/s. The release begins at 51.9 seconds, the minimum accumulator tank water depletion time. 6.20.4.1.5 LOCA Containment Integrity Results Plant input assumptions (identified in Section 6.20.4.1.2) are the same as, or slightly more restrictive, than in the licensing-basis analyses performed with the COCO code (Reference 18). Benchmarking between the Diablo Canyon COCO and GOTHIC models was performed to confirm consistency in the implementation of the plant input values. The containment pressure, steam temperature, and water (sump) temperature profiles of the OEHL peak pressure case are shown in Figures 6.20-3 through 6.20-5. Table 6.20-13 provides the transient sequence of events for the OEHL transient.

The containment pressure, steam temperature, and water (sump) temperature profiles of the OEPS long-term EQ temperature transient are shown in Figures 6.20-6 through 6.20-8 1. Tables 6.20-14 and 6.2-15 presents the sequence of events for the Unit 1 and Unit 2 OEPS transients, respectively.

The peak pressure (Figure 6.20-6) for the DEPS case occurs at 24.1 seconds after the end of the blowdown.

The fans begin to cool the containment at 48.7 seconds. Containment sprays begin injecting at 88.01 seconds. The pressure comes down as the steam generators reach equilibrium with the containment environment, but spikes up again at recirculation when the CCW temperature increases and the CCW flow rate to the CFCUs decreases.

The sensible heat release from the steam generator secondary system and RCS metal is completed at 3600 seconds, but at 3798 seconds, the RWST reaches a low level alarm and spray flow is terminated.

The containment pressure increases for a time and then begins to 1 The peak DEPS values are from Unit 2. 6.20-30 Revision 18 October 2008 DCPP UNITS 1 & 2 FSAR UPDATE decrease over the long term as the RHR heat exchangers and CFCUs remove the heat from the containment.

Table 6.20-21 summarizes the containment peak pressure and temperature results and pressure and temperature at 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> for EQ support and the acceptance limits for these parameters. A review of the results presented in Table 6.20-21 shows that the analysis margin (analysis margin is the difference between the calculated peak pressure and temperature and the acceptance limits) is maintained for Diablo Canyon with replacement steam generators.

From the GOTHIC analysis performed in support of the Diablo Canyon replacement steam generator program the containment peak pressure is 41.4 psig. PGE-10-54 (Reference

20) ev a lu ated the i ncreased ESF LOO P delay times that bound th e maximum 4 kV SL UR actuation t i me which resulted in a slight in crease in the peak pressure to 41.7 psig. This eva lu ation was performed only fo r the li mit in g Unit 2 DEHL and DEPS minimum EGGS cases. The Unit 1 cases and oth er U nit 2 cases are bounded and rema i n based on the de l ay times associated with a LOOP. The l ong t erm containment resu l ts were not imp acted and A a t 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />, the maximum containment pressure is 8.9 psig and the maximum temperature is 167.54 of. 6.20.4.1.6 Conclusion The DCPP containment can adequately account for the mass and energy releases that would result from the replacement steam generator program. The DCPP containment systems will continue to provide sufficient pressure and temperature mitigation capability to ensure that containment integrity is maintained.

The containment systems and instrumentation will continue to be adequate for monitoring containment parameters and release of radioactivity during normal and accident conditions and will continue to meet the DCPP licensing basis requirements with respect to GDC -13, -16, -38, -50, and -64 following installation of the replacement steam generators 6.20.4.2 Steamline Break Containment Response 6.20.4.2.1 Introduction and Background Containment integrity analyses are performed to ensure that pressure inside containment will remain below the containment building design pressure for a postulated secondary system pipe rupture. The mass and energy release analysis discussed in Section 6.20.3 is input to this analysis.

6.20.4.2.2 Input Parameters and Assumptions This section identifies the major input values that are used in the steamline break containment response analysis.

The assumed initial conditions and the input assumptions associated with the fan coolers and containment sprays are listed in 6.20-31 Revision 18 October 2008 DCPP UNITS 1 & 2 FSAR UPDATE Description", and "WCAP-8822(P)/8860(NP), "Mass and Energy Release Following a Steam Line Rupture," August 1983. 9. R. E. Land, Mass and Energy Releases Following a Steam Line Rupture, WCAP-8822 (Proprietary), WCAP-8860 (Non-Proprietary), September 1976. 10. T. W. T. Burnett, et al. LOFTRAN Code Description, WCAP-7907-P-A (Proprietary) and WCAP-7907-A (Non-Proprietary), April 1984. 11. M. P. Osborne and D. S. Love, Mass and Energy Releases Following a Steam Line Rupture, Supplement 1 -Calculations of Steam Superheat in Mass/Energy Releases Following a Steamline Rupture, WCAP-8822-S1-P-A (Proprietary), September 1986. 12. D. S. Huegel, et al. RETRAN-02 Modeling and Qualification for Westinghouse Pressurized Water Reactor Non-LOCA Safety Analyses, WCAP-14882-P-A (Proprietary), April 1999. 13. GOTHIC Containment Analysis Package Technical Manual. Version 7.2, NAI-8907 -06, Rev. 15, September 2004. 14. GOTHIC Containment Analysis Package Qualification Report, Version 7.2, NAI-8907-09, Rev. 8, September 2004. 15. License Amendment No. 169 for Kewaunee Nuclear Power Plant, Operating License No. DPR-43 (TAC No. MB6408), September 29, 2003. 16. GOTHIC Containment Analysis Package User Manual. Version 7.2, NAI-8907-02, Rev. 16, September 2004. 17. Brown and York, "Sprays formed by Flashing Liquid Jets", AICHE Journal. Volume 8, #2, May 1962. 18. F. M. Bordelon and E. T. Murphy, Containment Pressure Analysis Code (COCO), WCAP-8327 (Proprietary), WCAP-8326 (Non-Proprietary), July 1974. 19. Letter from Anthony C. McMurtray (NRC) to Thomas Coutu (NMC), "Enclosure 2, Safety Evaluation," September 29,2003. 20. West i nghouse l e tter PGE-10-54 , D i ab l o Can yon 2 30 k V Degraded V o l tage Eva l uat i on -E ngin ee ri ng Report Rev i s i on 1 , Octob er 1 5 , 2010. 6.20-34 Revision 18 October 2008 DCPP UNITS 1 & 2 FSAR UPDATE TABLE 6.20-1 SYSTEM PARAMETERS INITIAL CONDITIONS Unit 1 Unit 2 Parameters Value Value Core Thermal Power (MWt) 3479.0 Same RCS Total Flow Rate (Ibm/sec) 36888.88 37222.22 Vessel Outlet Temperature CF) 615.1 Same Core Inlet Temperature (OF) 549.5 550.1 Vessel Barrel-Baffle Configuration Downflow Upflow Initial Steam Generator Steam Pressure (psia) 881.0 Steam Generator Design Steam Generator Tube Plugging (%) 0 Initial Steam Generator Secondary Side Mass (Ibm) 132953.7 Assumed Maximum Containment Backpressure (psia) 61.7 Accumulator Water volume (ft3) per accumulator 850.0 N2 cover gas pressure (psia) 577.2 Temperature (OF) 120.0 SI Start Time, (sec) [total time from beginning of event which 31.1 includes the maximum delay from reaching the setpoint]

(1) Note: Core thermal power, RCS total flow rate, RCS coolant temperatures, and steam generator secondary side mass include appropriate uncertainty and/or allowance.

(1) PGE-10-54 (Reference

20) evaluated an increased SI start time that bounds the maximum 4 kV SLUR actuation time. This evaluation was performed only for the limiting Unit 2 OEHL and OEPS minimum EGGS cases. The Unit 1 cases are bounded by the Unit 2 cases and othe r Unit 2 cases remain based on the li sted delay time associated with a LOOP 885.0 Same 0 Same Same Same Same Same 31.3 Revision 18 October 2008 DCPP UN I TS 1 & 2 FSAR UPDATE TABLE 6.20-13 DOUBLE-ENDED HOT-LEG BREAK SEQUENCE OF E V ENTS Time (sec) Event Description 0.0 Break Occurs 1.1 Reactor Trip Occurs on Compensated Pressurizer Pressure Setpoint of 1859.7 psia and SG Throttle Valves Closed 4.0 Low Pressurizer Pressure SI Setpoint = 1694.7 psia Reached (Safety Injection begins IIIitl=lel:lt aAy after a 27 second delay and feedwater control valve starts to close) I MaiA GeAtFel Valve Gleseg I 1 M 4.9 Broken Loop Accumulator Begins Injecting Water I 15.,g.0 Intact Loop Accumulator Begins Injecting Water I 23.0 Peak Gas Temperature I 23.5 Peak Pressure 2 44 3.8 End of Blowdown Phase -+FaAsieAt MegeliA§ +eFFfliAateg 30.0 Transient Modeling Terminated I Revision 18 October 2008 DCPP UNITS 1 & 2 FSAR UPDATE TABLE 6.20-15 DIABLO CANYON UNIT 2 DOUBLE-ENDED PUMP SUCTION BREAK SEQUENCE OF EVENTS (MINIMUM SAFEGUARDS)

Time (sec) Event Description 0.0 Break Occurs and Loss-of-offsite Power is assumed 0.74 Hi-1 Co n t a i nment Setpo i nt (S I Actu a tion) R ea ch ed 1.2 3 Reactor Trip Occurs on Compensated Pressurizer Pressure Setpoint of 1859.7 psia and SG Throttle Valves Closed Low Pressurizer Pressure SI Setpoint = 1694.7 psia Reached (Safety Injection begins after a 27 second delay and feedwater control valve starts to close) 13.2 Main Feedwater Control Valve Closed Broken Loop Accumulator Begins Injecting Water Intact Loop Accumulator Begins Injecting Water 23.5 Pe a k Con ta i nment Gas Temperature a nd Pressure 26.2 End of Blowdown Phase Pumped Safety Injection Begins CFCUs On 5 ti-1.3 Broken Loop Accumulator Water Injection Ends Intact Loop Accumulator Water Injection Ends Containment Sprays Begin Injecting End of Reflood for Minimum Safeguards Case 56&..a 6.7 Mass and Energy Release Assumption:

Broken Loop SG Equilibration to 61.7 psia Mass and Energy Release Assumption:

Broken Loop SG Equilibration to 40.7 psia Mass and Energy Release Assumption:

Intact Loop SG Equilibration to 61.7 psia 1,678.0 Cold-Leg Recirculation Begins Mass and Energy Release Assumption:

Intact Loop SG Equilibration to 39.7 psia 3,600.0 End of Sensible Heat Release from Reactor Coolant System and Steam Generators 3,798.0 Containment Sprays Terminated Revision 18 October 2008 DCPP UNITS 1 & 2 FSAR UPDATE 25,200.0 21 , Switchover to Hot-Leg Recirculation 600.00 Revision 18 October 2008 DCPP UNITS 1 & 2 FSAR UPDATE TABLE 6.20-17 Sheet 1 of 2 DIABLO CANYON CONTAINMENT LOCA INTEGRITY ANALYSIS PARAMETERS Parameter Value Auxiliary SeNice Water Temperature CF) 64 RWST Water Temperature (OF) 90 Initial Containment Temperature (OF) 120 Initial Containment Pressure (psia) 16.0 Initial Relative Humidity (%) 18 Net Free Volume (fe) 2,550 , 000 Reactor Containment Fan Coolers Total CFCUs 5 Analysis Maximum 3 Analysis Minimum 2 Containment High Setpoint (psig) 5.0 Delay Time (sec) Without Offsite Power 48.0 Wi t h 4 kV S LUR actuation 52.0 CCW Flow to the CFCUs (gpm) During Injection 8,000 During Recirculation 7,450 Containment Spray Pumps Total CSPs 2 Analysis Maximum 2 Analysis Minimum 1 Flowrate (gpm) During Injection Table 6.2.0-18 During Recirculation 0 Containment High High Setpoint (psig) 24.7 Spray Delay Time (sec) Without Offsite Power after "P" signal 80 With 4 kV SLUR actuation afte r SI signal 100 Containment Spray Termination Time, (sec) Minimum Safeguards 3,798 Maximum Safeguards (1 CSP) 3,018 Maximum Safeguards (2 CSPs) 1,824 Revision 18 October 2008 DCPP UN I TS 1 & 2 FSAR UPDATE TABLE 6.20-17 Sheet 2 of 2 Parameter Value ECCS Recirculation E GCS Cold-Leg Recirculation Switchover , sec Minimum Safeguards 1 , 678 Maximum Safeguards (1 CSP) 1,033 Maximum Safeguards (2 CSPs) 829 Containment ECCS Cold-Leg Recirculation Flow, (gpm) Minimum Safeguards (1 RHR train) 3 , 252.3 Maximum Safeguards (2 RHR trains) 8,082.4 ECCS Hot-Leg Recirculation Switchover, sec 25,200 Containment ECCS Hot-Leg Recirculation Flow, (gpm) Minimum Safeguards (1 RHR train) 3,071.7 Maximum Safeguards (2 RHR trains) 4,576.8 Component Cooling Water System Total GCW Heat Exchangers 2 Analysis Maximum 2 Analysis Minimum 1 CGW Flow Rate to RHR Heat Exchanger (gpm per available HX) 4 , 800 ASW Flow Rate to CCW Heat Exchanger (gpm per available HX) 10,300 CCW Misc. Heat Loads (MBTU/hr)

During Injection 1.0 During Recirculation 2.0 CCW Flow Rate to Misc. Heat Loads (gpm) During Injection 2,500 During Recirculation 500 (1) PGE-10-54 (Reference

20) e v a luated the i ncreased ESF delay times th at bound the maximum 4 kV SL U R actuat ion time. This eva lu at ion w as performed only fo r the li miting Unit 2 DEHL and DEPS minimum EGGS cases. The Unit 1 cases and oth er Unit 2 are bounded and remain based on the delay times associated with a LOOP. Revision 18 Octobe r 2 008 DCPP UNITS 1 & 2 FSAR UPDATE TABLE 6.20-21

SUMMARY

OF LOCA PEAK CONTAINMENT PRESSURE AND TEMPERATURES Peak Peak Press@ Temp@ Break Location Pressure Time Gas Temp Time 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> 24 hours (psig) (sec) (OF) (sec) (psig) (OF) DEHL 41-A 4 1.7 n4 2 3.0 --DEPS min SI 39.8 244 23.5 259.3 244 23.5 8.9 167.5 Acceptance

<47 ---<50 -Criteria (1) These li miting Un it 2 r es ult s are b ased on the PGE-10-54 (R e ference 20) eva lu a tion of t h e in creased ESF de l a y tim es t hat bound t he ma ximum 4 kV SL U R actuat i on time. Revision 18 October 2008 DCPP UNITS 1 & 2 FSAR UPDATE into the reactor coolant loops. The reactor coolant pumps are assumed to be tripped at the beginning of the accident and the effects of pump coastdown are included in the blowdown analyses.

15.3.1.2 Analysis of Effects and Consequences For loss-of-coolant accidents due to small breaks less than 1 square foot, the NOTRUMP (Reference

12) computer code is used to calculate the transient depressurization of the RCS as well as to describe the mass and enthalpy of flow through the break. The NOTRUMP computer code is a one-dimensional general network code with a number of features.

Among these features are the calculation of thermal nonequilibrium in all fluid volumes, flow regime-dependent drift flux calculations with counter-current flooding limitations, mixture level tracking logic in multiple-stacked fluid nodes, and regime-dependent heat transfer correlations.

The NOTRUMP small break LOCA emergency core cooling system (ECCS) evaluation model was developed to determine the RCS response to design basis small break LOCAs and to address the NRC concerns expressed in NUREG-0611, "Generic Evaluation of Feedwater Transients and Small Break Loss-of-Coolant Accidents in Westinghouse-Designed Operating Plants." In NOTRUMP, the RCS is nodalized into volumes interconnected by flowpaths.

The broken loop is modeled explicitly, with the intact loops lumped into a second loop. The transient behavior of the system is determined from the governing conservation equations of mass, energy, and momentum applied throughout the system. A detailed description of the NOTRUMP code is provided in References 12 and 13. The use of NOTRUMPin the analysis involves, among other things, the representation of the reactor core as heated control volumes with the associated bubble rise model to permit a transient mixture height calculation.

The multinode capability of the program enables an explicit and detailed spatial representation of various system components.

In particular, it enables a proper calculation of the behavior of the loop seal during a loss-of-coolant transient.

Safety injection flow rate to the RCS as a function of the system pressure is used as part of the input. The SIS was assumed to be delivering water to the RCS 27 seconds after the generation of a safety injection signal. For the analysis, the SIS delivery considers pumped injection flow that is depicted in Figure 15.3-1 as a function of RCS pressure.

This figure represents injection flow from the SIS pumps based on performance curves degraded 5 percent from the design head. The 27-second delay includes time required for diesel startup and loading of the safety injection pumps onto the emergency buses. The effect of residual heat removal (RHR) pump flow is not considered here since their shutoff head is lower than RCS pressure during the time portion of the transient considered here. Also, minimum safeguards ECCS capability and operability have been assumed in these analyses.

15.3-3 Revision 19 May 2010 DCPP UNITS 1 & 2 FSAR UPDATE A tota l S I i njection delay time o f 42 seconds was evaluated i n PGE-10-54 (Reference

29) i n order to bound the max im um 4 kV SLUR actuation t i me. Peak cladding temperature ana ly ses are performed with the LOCTA IV (R eference 4) code that determines the RCS pressure, fuel rod power history, steam flow past the uncovered part to the core, and mixture height history. 15.3.1.3 Results 15.3.1.3.1 Reactor Coolant System Pipe Breaks This section presents the results of a spectrum of small break sizes analyzed.

The small break analysis was performed at 102 percent of the Rated Core Power (3411 MWt) , a Total Peaking Factor (FQT) of 2.70, a Thermal Design Flow of 87,700/88,500 gpmlloop (Unit 1 / Unit 2) and a steam generator tube plugging level of 10 percent. For Unit 2, the small break analysis was performed for the upflow core barrel/baffle configuration and upper head temperature reduction.

The limiting small break size was shown to be a 3-inch diameter break in the cold leg. In the analysis of this limiting break, an RCS Tavg window of 577.3/ 577.6°F, +5°F, -4°F (Unit 1 / Unit 2) was considered.

The high Tavg cases were shown to be more limiting than the Low Tavg cases and therefore are the subject of the remaining discussion.

The time sequence of events and the fuel cladding results for the breaks analyzed are shown in Tables 15.3-1 and 15.3-2. During the earlier part of the small break transient, the effect of the break flow is not strong enough to overcome the flow maintained by the reactor coolant pumps through the core as they are coasting down following reactor trip. Therefore, upward flow through the core is maintained.

The resultant heat transfer cools the fuel rods and cladding to very near the coolant temperature as long as the core remains covered by a two-phase mixture. This effect is evident in the accompanying figures. The depressurization transients for the limiting 3-inch breaks are shown in Figure 15.3-9. The extent to which the core is uncovered for these breaks is presented in Figure 15.3-11. The maximum hot spot cladding temperature reached during the transient, including the effects of fuel densification as described in Reference 3, is 1391 / 1288°F (Unit 1 / Unit 2). The peak cladding temperature transients for the 3-inch breaks are shown in Figure 15.3-13. The top core node vapor temperatures for the 3-inch breaks are shown in Figure 15.3-33. When the mixture level drops below the top of the core, the top core node vapor temperature increases as the steam superheats along the exposed portion of the fuel. The rod film coefficients for this phase of the transients are given in Figure 15.3-34. The hot spot fluid temperatures are shown in Figure 15.3-35 and the break mass flows are shown in Figure 15.3-36. The core power (dimensionless) transient following the accident (relative to reactor scram time) is shown in Figure 15.3-8. The reactor shutdown time (4.7 sec) is equal to 15.3-4 Revision 19 May 2010 DCPP UNITS 1 & 2 FSAR UPDAT E th e reactor trip s ign a l proce ss ing time (2.0 s econd s) plu s 2.7 s econd s for complete rod insertion. During this rod insertion period, th e reactor i s conservatively assumed to operate at 102 percent rated power. The small break an a lyses considered 17x17 Vant a g e 5 fuel with IFM's , ZIRLO cl a dding, a nd a n a xi a l bl a nk e t. F ully e nrich e d a nnul ar pe ll e t s , as part of a n ax i a l b l a nk et co r e des i g n , w e r e mode l ed exp li ci tly in t hi s a n a ly s i s. The results when modeling the enriched annular pellets were not significantly different than the results from solid pellet modeling.

Several figures are also presented for the additional break sizes analyzed.

Figures 15.3-37, 15.3-2, and 15.3-40 present the RCS pressure transient for the 2-, 4-, and 6-inch breaks, respectively. Figures 15.3-38 and 15.3-3 present the core mixture height plots for both breaks. The peak cladding temperature transients for the 2-inch breaks are shown in Figure 15.3-39. The peak cladding temperature transients for the 4-inch breaks are shown in Figure 15.3-4. These results are not available for the 6-inch break because the core did not uncover for this transient.

The small break analysis was performed with the Westinghouse ECCS Small Break Evaluation Model (References 12 and 4) approved for this use by the Nuclear Regulatory Commission in May 1985. An approved cold leg SI condensation model, COSI (Reference 26), was utilized as part of the Evaluation Model. Th e PG E-10-54 (Re f er e n ce 29) ev a lu a tion determ in ed th a t th e additi o na l EGGS de l ay du e to a 4 kV SL U R actu a ti on would h a v e an i ns i gn i ficant e ff e ct on the SBLOGA th e rma l hyd r au li c results pr ese nt e d i n thi s se ct i on. Ther e f ore , th e SB LOGA cases a na l y z ed i n th i s sect i on w i th a n EGGS d e l a y of 27 second s did not r e quire re vi s io n and remain b o unding fo r the 42 sec on d d e l a y ass oc i at ed w i th th e maximum 4 kV SL U R actuat i on tim e. 15.3.1.4 Conclusions Analyses presented in this section show that the high-head portion of the ECCS, together with the accumulators, provides sufficient core flooding to keep the calculated peak cladding temperatures below required limits of 10 CFR 50.46. Hence adequate protection is afforded by the ECCS in the event of a small break LOCA. 15.3.2 MINOR SECONDARY SYSTEM PIPE BREAKS 15.3.2.1 Identification of Causes and Accident Description Included in this grouping are ruptures of secondary system lines which would result in steam release rates equivalent to a 6-inch diameter break or smaller. 15.3.2.2 Analysis of Effects and Consequences Minor secondary system pipe breaks must be accommodated with the failure of only a small fraction of the fuel elements in the reactor. Since the results of analysis presented 15.3-5 Revision 19 May 2010 DCPP UNITS 1 & 2 FSAR UPDATE 22. Deleted in Revision 12. 23. Deleted in Revision 13. 24. Deleted in Revision 13. 25. Deleted in Revision 13. M-:-26. Thompson, C. M., et aI., Addendum to the Westinghouse Small Break LOCA Evaluation Model Using the NOTRUMP Code: Safety Injection Into the Broken Loop and the COSI Condensation Model, WCAP-10054-P-A, Addendum 2, Rev. 1, (proprietary), October 1995. 27. T. Q. Nguyen, et. aI., Qualification of the PHOENIX-P/ANC Nuclear Design System for Pressurized Water Reactor Cores, WCAP-11596-P-A, June 1988. 28. S. L. Davidson, (Ed), et. aI., ANC: Westinghouse Advanced Nodal Computer Code, WCAP-10965-P-A, September 1986. 29. Westinghous e l etter PGE-10-54 , D i ab l o Canyon 230 kV Degr aded Volt age Eva lu ation -Eng in eer ing Report Re vi sion 1 , October 15, 2010. 15.3-13 Revision 19 May 2010 DCPP UNITS 1 & 2 FSAR UPDATE for th e D E CLG b r ea k. T h ese pr e dictions a re c omp a red to th e pr e diction s b ase d on E qu at ion 1 5.4.1-1, a nd a ddition a l bi ases a n d un ce rt a inties a r e a ppli e d wh e r e appropriate. T h e superpos i t i on ass um pt i on v er i ficat i on step w as perfor m ed for the Un it 1 reana l ys i s (Reference 67). These calculations resulted in an adjustment of the bias and uncertainty that is required for the reanalysis methodology.

The estimate of the PCT at 95 percent probability is determined by finding that PCT below which 95 percent of the calculated PCTs reside. This estimate is the licensing basis PCT, under the revised ECCS rule. The results of the Best Estimate LBLOCA analysis are presented in Table 15.4.1-2A.

The difference between the 95 percentile PCT and the average PCT increases with each subsequent PCT period, due to propagation of uncertainties.

15.4.1.7 A Additional Evaluations Zircaloy Clad Fuel: An evaluation of Zircaloy clad fuel has shown that the Zircaloy clad fuel is bounded by the results of ZIRLO clad fuel analysis.

IFBA Fuel: An evaluation of IFBA fuel has shown that the IFBA fuel is bounded by the results of the non-IFBA fuel analysis.

T AVG Coastdown:

An end-of-cycle, full power T AVG coastdown at 565°F evaluation was performed and concluded that there would be no adverse effect on the Best Estimate LBLOCA analysis as a T AVG window between 565 and 577.3°F was explicitly modeled in the Best Estimate LBLOCA analysis.

These evaluations have been shown to continue to apply for the Unit 1 reanalysis (Reference 67). 15.4.1.8A Unit 1 10 CFR 50.46 Results It must be demonstrated that there is a high level of probability that the limits set forth in 10 CFR 50.46 are met. A total EGGS injection delay time of 42 seconds was evaluated in PGE-10-54 (Reference

73) in order to bound the maximum 4 kV SLUR actuation time. The evaluation was performed for the limiting cas e and a minor PGT penalty was assessed per 10 GFR 50.46 due to the estimated additional core heatup that could occur due to the increased EGGS delay. Since minor PGT assessments per 10 GFR 50.46 do not require a complete analysis , the spectrum of cases for the Best Estimate LBLOGA results presented in this section remain based on the 27 second EGGS delay time associated with a LOOP. These Best Estimate LBLOGA results with the PGT penalty assessed and tracked per 10 GFR 50.46 bound the maximum 4 kV SLUR action time. The demonstration that these limits are met is as follows: 15.4-18 Revision 19 May 2010 DCPP UNITS 1 & 2 FSAR UPDATE As discussed in Section 15.4.1.2.6, the large break LOCA transient can be divided into convenient time periods in which specific phenomena occur, such as various hot assembly heatup and cooldown transients.

For a typical large break, the blowdown period can be divided into the critical heat flux (CHF) phase, the upward core flow phase, and the downward core flow phase. These are followed by the refill, reflood, and long-term cooling periods. Specific important transient phenomena and heat transfer regimes are discussed below, with the transient results shown in Figures 15.4.1-1 B to 15.4.1-12B.

15.4.1.88 10 CFR 50.46 Requirements It must be demonstrated that there is a high level of probability that the limits set forth in 10 CFR 50.46 are met. A total EGGS injection delay time of 42 seconds was evalu ated in PGE-1 0-54 (Ref erence 73) i n order to bound the maximum 4 kV SLUR ac tuation time. The evalua tion was performed for the l im i t in g case and a minor PGT penalty was asses sed per 10 GFR 50.46 due to the estImated additiona l core h eatup that cou l d occur due to th e i ncreased EGGS delay. Since minor PGT a s sessme nts p er 10 GFR 50.46 do not requ ire a co mp l ete reanalys i s, the spectrum of cases fo r the Be st Estim ate LBLOGA results presented in t his section remain based o n the 27 second EGGS delay tim e associated w i th a LOOP. Thes e Best Estimate LBLOGA results with the PGT penalty assessed and tracked per 10 GFR 50.46 bound the maximum 4 kV SL U R action time. The demonstration that these limits are met is as follows: (1) Since the resulting PCT for the limiting case is 1872 of, the analysis confirms that 10 CFR 50.46 acceptance criterion (b)(1), i.e., "Peak Cladding Temperature less than 2200 of, is met. The results are shown in Table 15.4.1-2B.

(2) Since the resulting local maximum oxidation (LMO) for the limiting case is 1.64 percent, the analysis confirms that 10 CFR 50.46 acceptance criterion (b)(2), i.e., "Local Maximum Oxidation of the cladding less than 17 percent," is met. The results are shown in Table 15.4.1-2B.

(3) The limiting hot fuel assembly rod has a calculated maximum oxidation of 0.17 percent. Since this is the hottest fuel rod within the core, the calculated maximum oxidation for any other fuel rod would be less than this value. For the low power peripheral fuel assemblies, the calculated oxidation would be significantly less than this maximum value. The core wide oxidation (CWO) is essentially the sum of all calculated maximum oxidation values for all of the fuel rods within the core. Therefore, a detailed CWO calculation is not needed because the calculated sum will always be less than 0.17 percent. Since the resulting CWO is conservatively assumed to be 0.17 percent, the analysis confirms that 10 CFR 50.46 acceptance criterion (b)(3), i.e., "Core-Wide Oxidation less than 1 percent," is met. The results are shown in Table 15.4.1-2B.

15.4-23 Revision 19 May 2010 DCPP UNITS 1 & 2 FSAR UPDATE 72. PGE-10-56, "PG&E Diablo Canyon Units 1 and 2, Steam Generator Tube Rupture Margin to Overfill Analysis (CN-CRA-10-45 Rev. 0)," October 18, 2010 73. Westinghouse letter PGE-10-54 , Diablo Canyon 230 kV Degraded Voltage E v a l uat i on -Eng in ee r i ng Report Rev i s i on 1 , Octob er 1 5, 2010. 15.4-72 Revision 19 May 2010 DCPP UNITS 1 & 2 FSAR UPDATE TABLE 15.3-1 TIME SEQUENCE OF EVENTS -SMALL BREAK LOCA Unit 1 2-inch 3-inch 4-inch 6-inch Transient Initiated, sec 0 0 0 0 Reactor Trip Signal, sec 43.58 18.32 10.55 5.9 Safety Injection Signal, sec 58 26.8 16.57 8.58 Safety Injection Begins(1), sec 85 53.8 43.57 35.58 Loop Seal Clearing Occurs(2), sec 1197 514 300 110 Top of Core Uncovered(3), sec 1796 941 635 N/A Accumutator Injection Begins, sec N/A 1984 885 385 Top of Core Recovered, sec 6500 3170 2545 N/A RWST Low Level, sec 1700 1689 1664 1640 Unit 2 2-inch 3-inch 4-inch 6-inch Transient Initiated, sec 0 0 0 0 Reactor Trip Signal, sec 44.72 18.78 10.82 6.11 Safety Injection Signal, sec 59.45 27.41 16.68 9 Safety Injection Begins(1), sec 86.45 54.41 43.68 36 Loop Seal Clearing Occu rs(2) , sec 1360 575 290 120 Top of Core Uncovered(3), sec 3200 722 770 N/A Accumulator Injection Begins, sec N/A 3050 985 400 Top of Core Recovered, sec N/A 3215 1630 N/A RWST Low Level, sec 1708 1690 1666 1641 (1) These SBLOCA cases assume Safety Injection flow begins 27.0 seconds (SI delay time) after the safety injection signal is reached based on a LOOP. The evaluation in PGE-10-5 4 (Reference

29) determined that an increased SI injection delay time of 42 seconds had an insignificant effect on these SBLOCA thermal hydraulic results such that they remain conservatively bounding for the maximum SLUR actuation time. (2) Loop seal clearing is considered to occur when the broken loop seal vapor flow rate is sustained above 1 Ibm/s. (3) Top of core uncovery time is taken as the time when the core mixture level is sustained below the top of the core elevation.

Revision 19 May 2010 DCPP UNITS 1 & 2 FSAR UPDATE TABLE 15.3-2 FUEL CLADDING RESULTS -SMALL BREAK LOCA Unit 1 2-inch 3-inch 4-inch peT (OF) 907 1391 1241 peT Time (s) 2173.3 1891.7 975.8 peT Elevation (ft) 10.75 11.25 11.00 Burst Time (s) (1) N/A N/A N/A Burst Elevation (ft) (1) N/A N/A N/A Maximum Hot Rod Transient Zr02 (0/0) 0.01 0.38 0.07 Maximum Hot Rod Transient Zr02 Elev. (ft) 10.75 11.25 10.75 Hot Rod Average Transient Zr02 (%) 0.01 0.06 0.01 Unit 2 2-inch 3-inch 4-inch peT (OF) 814 1288 1004 peT Time (s) 4838.3 1961.8 1079.2 peT Elevation (ft) 11.00 11.25 10.75 Burst Time (s) (1) N/A N/A N/A Burst Elevation (ft) (1) N/A N/A N/A Maximum Hot Rod Transient Zr02 (0/0) 0.01 0.18 0.01 Maximum Hot Rod Transient Zr02 Elev. (ft) 11.00 11.25 10.75 Hot Rod Average Transient Zr02 (0/0) 0 0.03 0.01 (1) Burst was not predicted to occur for any break size. (2) Th e eva l uation i n PGE-10-54 (Refer en ce 29) de t ermined that an i ncrea sed SI inj ect i on de l ay time of 42 secon ds had an i nsignificant effect on these SB L OCA thermal h ydrau l ic re sul ts such th at they rema i n conserv at i ve l y bou nding for t he m ax i m um SLU R a c t u ati on t i me. Revision 19 May 2010 DCPP UNITS 1 & 2 FSAR UPDATE TABLE 1S.4.1-1A UNIT 1 BEST ESTIMATE LARGE BREAK LOCA TIME SEQUENCE OF EVENTS B o sec. Break occurs L Reactor trip (pressurizer pressure or high containment pressure) 0 Pumped SI signal (pressurizer pressure or high containment pressure)

W Accumulator injection begins 0 Pumped ECCS injection begins (offsite power available) 0 Containment heat removal system starts (offsite power available)

W 20-25 sec. End of bypass N End of blowdown R E Pumped ECCS injection begins (loss of offsite power) (1) I F I Containment heat removal system starts (loss of offsite power) L L 35-40 sec. Bottom of core recovery R E F Accumulators empty L 0 0 0 5 min. Core quenched L 0 N G Switch to cold leg recirculation on RWST low level alarm T E R M Switch to hot leg/cold leg_ recirculation C 0 0 L I N G (1) A total SI injection delay time of 42 seconds that bounds the ma x imum 4 kV SLUR actuation time was evaluated in PGE-10-54 (Reference 73). H owever, these reported sequence times still remain characteristic for the limiting Best Estimate LBLOCA case. Revision 18 October 2008 DCPP UNITS 1 & 2 FSAR UPDATE TABLE 15.4.1-1B UNIT 2 BEST ESTIMATE LARGE BREAK SEQUENCE OF EVENTS FOR LIMITING PCT CASE Event Time (sec) Start of Transient 0.0 Safety Injection Signal 6.0 Accumulator Injection Begins 13.0 End of Blowdown 29.0 Safety Injection Begins (1) 33.0 Bottom of Core Recovery 37.0 Accumulator Empty 48.0 PCT Occurs 110.0 Hot Rod Quench 285.0 End of Transient 500.0 (1) A total EGGS i njection delay time of 42 seco nds was evaluated i n PGE-10-54 (Refe rence 73) i n order to bound the maximum 4 kV SLUR actuation time. Ho wever, these reported seq uenc e tim es still remain characteristic for the li miting Best Estimate LOGA case. Revision 18 October 2008 DCPP UNITS 1 & 2 FSAR UPDATE TABLE 1S.4.1-2A UNIT 1 BEST ESTIMATE LARGE BREAK LOCA ANALYSIS RESULTS Component Blowdown Peak First Reflood Peak Second Reflood Peak PCTaverage Maximum Oxidation

<11% Total Oxidation

<0.890/0 (1) A total SI injection delay time of 42 seconds that bounds the maximum 4 kV SLUR actuation time was evaluated in PGE-10-54 (Reference

73) and a PCT penalty was assessed per 10 CFR 50.46 with respect to these l imiting Unit 1 Best Estimate LBLOCA results. However , these reported oxidation results remain conservatively bounding , Revision 18 October 2008 DCPP UNITS 1 & 2 FSAR UPDATE TABLE 15.4.1-2B UNIT 2 BEST ESTIMATE LARGE BREAK LOCA ANALYSIS RESULTS 95/95 PCT 95/95 LMO 95/95 CWO PCT -Peak Cladding Temperature LMO -Local Maximum Oxidation CWO -Core Wide Oxidation Result 1,872°F 1.64% 0.17% Criterion

< 2,200°F <17% < 1% (1) A to ta l S I inj e ct ion de l ay time o f 42 sec o nds th at bound s t he m ax i mum 4 kV SL U R a ct uation ti me was eva l uated i n P G E-1 0-54 (Reference

73) and a PCT pen a lty was assessed per 1 0 CF R 50.4 6 wi th r espect to these l im i t i ng Unit 2 Best Est i mate LBLOCA re s u lt s. Ho w ev er, t hese r eported ox i dat i on r e sul ts r emain conserva ti ve ly bou nding , Revision 18 October 2008 1.0 2.0 DCPP UNITS 1 & 2 FSAR UPDATE TABLE 1S.4.1-3A UNIT 1 KEY BEST ESTIMATE LARGE BREAK LOCA PARAMETERS AND REFERENCE TRANSIENT ASSUMPTIONS Parameter Reference Transient Plant Physical Description
a. Dimensions Nominal b. Flow resistance Nominal c. Pressurizer location Opposite broken loop d. Hot assembly location Under limiting location e. Hot assembly type 17x17 V5+ w/ZIRLO clad f. SG tube plugging level High (15%) Plant Initial Operating Conditions 2.1 Reactor Power a. Core average linear heat rate Nominal -100% of uprated power (3411 MWt) b. Peak linear heat rate (PLHR) Derived from desired Technical Specifications (TS) limit and maximum base load c. Hot rod average linear heat rate (HRFLUX) Derived from TS F L).H Sheet 1 of 4 Uncertainty or Bias Bounded Bounded Bounded Bounded(a)

Revision 18 October 2008 DCPP UNITS 1 & 2 FSAR UPDATE TABLE 1S.4.1-3A Sheet 2 of 4 Parameter Reference Transient Uncertainty or Bias d. Hot assembly average heat rate HRFLUX/1.04

e. Hot assembly peak heat rate PLHR/1.04
f. Axial power distribution (PBOT, PMID) Figure 3-2-10 of Reference 9
g. Low power region relative power (PLOW) 0.3 Bounded(a)
h. Hot assembly burnup BOL Bounded i. Prior operating history Equilibrium decay heat Bounded j. Moderator Temperature Coefficient (MTC) TS Maximum (0) Bounded k. HFP boron 800 ppm Generic 2.2 Fluid Conditions I a. Tavg Max. nominal Tavg = 577.3°F Nominal is bounded, uncertainty is in
b. Pressurizer pressure Nominal (2250.0 psia)
c. Loop flow 85000 gpm
d. TUH Best Estimate 0 e. Pressurizer level Nominal (1080 fe) 0 f. Accumulator temperature Nominal (102.5°F)
g. Accumulator pressure Nominal (636.2 psia)

Revision 18 October 2008 Parameter

h. Accumulator liquid volume i. Accumulator line resistance
j. Accumulator boron 3.0 Accident Boundary Conditions
a. Break location b. Break type c. Break size d. Offsite power e. Safety injection flow f. Safety injection temperature
g. Safety injection delay h. Containment pressure i. Single failure j. Control rod drop time DCPP UNITS 1 & 2 FSAR UPDATE TABLE 15.4.1-3A Reference Transient Nominal (850 fe) Nominal Minimum Cold leg Guillotine Nominal (cold leg area) Off (RCS pumps tripped) Minimum Nominal (68°F) Max delay sec (with offsite powe r) $ 27. 0 sec (wi t h LOOP) S hee t 3 of 4 Uncerta inty or Bias Bounded Bounded Bounded(a)

Bounded Bounded $ 42.0 sec (with 4 kV SLUR actuation)

Minimum based on WCIT M&E Bounded ECCS: Loss of 1 SI train Bounded No control rods Bounded Revision 1 8 O c to be r 2 0 0 8 DCPP UNITS 1 & 2 FSAR UPDATE TABLE 1S.4.1-3A Sheet 4 of 4 , Parameter Reference Transient Uncertainty or Bias 4.0 Model Parameters

a. Critical Flow Nominal (as coded)
b. Resistance uncertainties in broken loop Nominal (as coded)
c. Initial stored energy/fuel rod behavior Nominal (as coded)
d. Core heat transfer Nominal (as coded)
e. Delivery and bypassing of ECC Nominal (as coded) Conservative
f. Steam binding/entrainment Nominal (as coded) Conservative
g. Noncondensable gases/accumulator nitrogen Nominal (as coded) Conservative
h. Condensation Nominal (as coded) (a) Confirmed by plant-specific analysis. (b) Assumed to be result of loop resistance uncertainity.

Notes: 1.

MOD indicates this uncertainty is part of code and global model uncertainty.

2.

indicates this uncertainty is part of power distribution uncertainty.

3.

indicates this uncertainty is part of initial condition uncertainty.

Revision 18 October 2008 DCPP UNITS 1 & 2 FSAR UPDATE TABLE 15.4.1-3B Sheet 1 of 3 UNIT 2 KEY BEST ESTIMATE LARGE BREAK LOCA PARAMETERS AND INITIAL TRANSIENT ASSUMPTIONS Parameter Initial Transient Range/Uncertainty 1.0 Plant Physical Description

a. Dimensions Nominal Sampled b. Flow resistance Nominal Sampled c. Pressurizer location Opposite broken loop Bounded d. Hot assembly location Under limiting location Bounded e. Hot assembly type 17x17 V5 + with ZIRLOŽ cladding, Bounded Non-IFBA f. Steam generator tube plugging level High (15%) Bounded(a) 2.0 Plant Initial Operating Conditions 2.1 Reactor Power a. Core average linear heat rate (AFLUX) Nominal -Based on 100% thermal power Sampled (3468 MWt) b. Hot rod peak linear heat rate (PLHR) Derived from desired Technical Sampled Specification limit Fa = 2.7 and maximum baseload Fa = 2.1 c. Hot rod average linear heat rate (HRFLUX) Derived from Technical Specification Sampled = 1.7 d. Hot assembly average heat rate (HAFLUX) HRFLUX/1.04 Sampled e. Hot assembly peak heat rate (HAPHR) PLHR/1.04 Sampled f. Axial power distribution (PBOT, PMID) Figure 15.4.1-15B Sampled g. Low power region relative power (PLOW) 0.3 Bounded(a)
h. Cycle burnup -2000 MWD/MTU Sampled i. Prior operating history Equilibrium decay heat Bounded Revision 19 May 2010 DCPP UNITS 1 & 2 FSAR UPDATE TABLE 15.4.1-3B Sheet 2 of 3 Parameter Initial Transient Ran g e/Uncertainty 2.0 Plant Initial Operating Conditions (continued)
j. Moderator temperature coefficient Technical Specification Maximum (0) Bounded k. HFP boron 800 ppm Gener i c 2.2 Fluid Conditions
a. Tavg High Nominal Tavg = 577.6°F Bounded(a), Sampled b. Pressurizer pressure Nominal (2250.0 psia) Samp l ed c. Loop flow 85,000 gpm Bounded d. Upper head fluid temperature Tcold 0 e. Pressurizer level Nominal 0 f. Accumulator temperature Nominal (102.5°F)

Samp l ed g. Accumulator pressure Nominal (636.2 psia) Samp l ed h. Accumulator liquid volume Nominal (850 fe) Samp l ed i. Accumulator line resistance Nominal Samp l ed j. Accumulator boron Minimum (2200 ppm) Bounded 3.0 Accident Boundary Conditions

a. Break location Cold leg Bounded b. Break type Guillotine (DECLG) Samp l ed c. Break size Nominal (cold leg area) Samp l ed d. Offsite power Loss of offsite power Bounded(a)
e. Safety injection flow Minimum Bounded f. Safety injection temperature Nominal (68°F) Samp l ed g. Safety injection delay Max fmHm delay ::;17.0 sec (with offsite power) Bounded ::; 27.0 sec (with LOOP) ::; 42.0 sec (with 4 kV SLUR actuation)

S8S) Revision 1 9 May 2010 DCPP UNITS 1 & 2 FSAR UPDATE TABLE 15.4.1-3B Sheet 3 of 3 Parameter Initial Transient Range/Uncertainty 3.0 Accident Boundary Conditions (continued)

h. Containment pressure Bounded -Lower (conservative)

Bounded than pressure curve shown in Figure 15.4.1-14B.

i. Single failure ECCS: Loss of one safety injection train; Bounded Containment pressure:

all trains operational

j. Control rod drop time No control rods Bounded 4.0 Model Parameters
a. Critical flow Nominal (CD = 1.0) Sampled b. Resistance uncertainties in broken loop Nominal (as coded) Sampled c. Initial stored energy/fuel rod behavior Nominal (as coded) Sampled d. Core heat transfer Nominal (as coded) Sampled e. Delivery and bypassing of emergency core coolant Nominal (as coded) Conservative
f. Steam binding/entrainment Nominal (as coded) Conservative
g. Noncondensable gases/accumulator nitrogen Nominal (as coded) Conservative
h. Condensation Nominal (as coded) Sampled -------(a) Per Confirmatory Study results (Section 15.4.1.1.2.5)

Revision 19 May 2010 DCPP UNITS 1 & 2 FSAR UPDATE TABLE 15.4.1-7A Sheet 1 of 3 UNIT 1 PLANT OPERATING RANGE ALLOWED BY THE BEST-ESTIMATE LARGE BREAK LOCA ANALYSIS Parameter Operating Range 1.0 Plant Physical Description

a. Dimensions No in-board assembly grid deformation assumed due to LOCA + SSE b. Flow resistance N/A c. Pressurizer location N/A d. Hot assembly location Anywhere in core e. Hot assembly type Fresh 17X17 V5, ZIRLO, or Zircaloy cladding, 1.5X IFBA or non-IFBA f. SG tube plugging level 515% g. Fuel assembly type Vantage 5, ZIRLO, or Zircaloy cladding, 1.5X IFBA or non-IFBA 2.0 Plant Initial Operating Conditions 2.1 Reactor Power a. Core average linear heat rate Core power 5 102% of 3411 MWt b. Peak linear heat rate Fo 52.7 c. Hot rod average linear heat rate FL'1H 51.7 d. Hot assembly average linear heat rate -P HA 51.57 e. Hot assembly peak linear heat rate FOHA 5 2.7/1.04 Revision 19 May 2010 2.2 f. g. h. i. j. k. DCPP UNITS 1 & 2 FSAR UPDATE TABLE 15.4.1-7A Parameter Operating Range Axial power distribution (PBOT, PMID) Figure 15.4.1-15A Low power region relative power (PLOW) 0.3 ::;; PLOW::;; 0.8 Hot assembly burnup ::;; 75,000 MWD/MTU, lead rod Prior operating history All normal operating histories MTC ::;; 0 at HFP HFP boron Normal letdown Fluid Conditions
a. Tavg 560.0::;;

Tave ::;; 582.3°F b. Pressurizer pressure 2190::;; PRcs::;; 2310 psia c. Loop flow ;;::: 85,000 gpm/loop d. TUH Current upper internals

e. Pressurizer level Normal level, automatic control f. Accumulator temperature 85 ::;; accumulator temperature::;;

120°F g. Accumulator pressure 579 ::;; P ACC ::;; 664 psig h. Accumulator volume 814::;; Vacc::;; 886 fe i. Accumulator fLlD Current line configuration Sheet 2 of 3 Revision 19 May 2010 DCPP UNITS 1 & 2 FSAR UPDATE TABLE 15.4.1-7A Shee t 3 of 3 Parameter Operating Range j. Minimum accumulator boron 2200 ppm 3.0 Accident Boundary Conditions

a. Break location N/A b. Break type N/A c. Break size N/A d. Offsite power Available or LOOP e. Safety injection flow Figure 15.4.1-13A
f. Safety injection temperature 46 ::;; SI Temperature::;;

90°F g. Safety injection delay ::;;17 seconds (with oftsite power) ::;; 27 seconds (with LOOP) ::;; 42.0 sec (with 4 kV SLUR actuation)

h. Containment pressure Bounded -see Figure 15.4.1-14A
i. Single failure Loss of one train I j. Control rod drop time N/A Revision 1 9 M a y 2 0 10 DCPP UNITS 1 & 2 FSAR UPDATE TABLE 15.4.1-7B Sheet 1 of 2 UNIT 2 PLANT OPERATING RANGE ALLOWED BY THE BEST-ESTIMATE LARGE BREAK LOCA ANALYSIS Parameter Operating Range 1.0 Plant Physical Description a) Dimensions No in-board assembly grid deformation during LOCA + SSE b) Flow resistance N/A c) Pressurizer location N/A i d) Hot assembly location Anywhere in core interior (149 locations)(a) e) Hot assembly type Fresh 17x17 V5+ fuel with ZIRLO Ž cladding 1) Steam generator tube plugging level g) Fuel assembly type 17x17 V5+ fuel with ZIRLOŽ cladding, non-IFBA or IFBA 2.0 Plant Initial Operating Conditions 2.1 Reactor Power a) Core average linear heat rate Core power S 100.3% of 3,468 MWt b) Peak linear heat rate Fa S 2.7 c) Hot rod average linear heat rate FaH S 1.7 d) Hot assembly average linear heat rate P HA ::. 1.7/1.04 e) Hot assembly peak linear heat rate FaHA 2.7/1.04 1) Axial power distribution (PBOT, PMID) See Figure 15.4.1-15B.

g) Low power region relative power (PLOW) 0.3 S PLOW S 0.8 h) Hot assembly burnup S 75,000 MWD/MTU, lead rod (a) i) Prior operating history All normal operating histories j) Moderator temperature coefficient SO at HFP k) HFP boron (minimum) 800 ppm (at BOL) 2.2 Fluid Conditions a) Tav9 565 -5°F S Tav9 S 577.6 + 5°F b) Pressurizer pressure 2250 -60 psia S PRes S 2250 + 60 psia Revision 18 October 2008 DCPP UNITS 1 & 2 FSAR UPDATE TABLE 15.4.1-7B Sheet 2 of 2 Parameter Operating Range c) Loop flow 85,000 gpm/loop d) TUH Converted upper internals, T COLD UH e) Pressurizer level Nominal level, automatic control 1) Accumulator temperature 85°F ;5; T Acc;5; 120°F g) Accumulator pressure 579 psi a ;5; P ACC ;5; 664 psi a h) Accumulator liquid volume 814 fe;5; V Acc;5; 886 fe i) Accumulator fl-/D Current line configuration j) Minimum accumulator boron 2200 ppm 3.0 Accident Boundary Conditions a) Break location N/A b) Break type N/A I I c) Break size N/A d) Offsite power Available or LOOP e) Safety injection flow See Figure 15.4.1-13B.

1) Safety injection temperature 46°F ;5; SI Temp ;5; 90°F g) Safety injection delay ;5; 17 seconds (with offsite power) ;5; 27 seconds (with LOOP) 42.0 sec (wit h 4 kV SLUR actuation) h) Containment pressure See Figure 15.4.1-14B and raw data in Table 15.4.1-58.

i) Single failure All trains operable(b) j) Control rod drop time N/A (a) 44 peripheral locations will not physically be lead power assembly. (b) Analysis considers loss of one train of pumped ECCS. Revision 18 October 2008 Commitments Commitment 1 Enclosure Attachment 5 PG&E Letter DCL-11-072 In order to ensure control of the setpoints for the proposed changes to TS SR 3.3.5.3 and the TS SR 3.3.5.3 Bases, the 10 CFR 50.59 controlled surveillance test procedures applicable to TS SR 3.3.5.3 will be updated as required as part of implementation of the amendment for each unit. Commitment 2 The "Equipment Control Guidelines" (ECGs) will be updated as part of implementation of the amendment for each unit to identify the methodologies used to determine the found and as-left tolerances.

The ECGs are documents controlled under 10 CFR 50.59 and are incorporated into the FSAR by reference.

PG&E Calculation 357S-DC Enclosure Attachment 6 PG&E Letter DCL-11-072 DCPP Form 69-20132 (04/13/10)

Design Calculation Cover Sheet CF3.1D4 Attachment 4 Page 1 of 152 Unit(s): 1 &2 File No.: SAP Calculation No.: 9000041128-001 Design Calculation:

IZI YES D NO System No.: 63 ----------------

Legacy No.: 357S-DC Rev 1 Responsible Group: EDE ------------------------

Quality Classification:

Q Structure, System or Component:

4.16 kV Bus Under-Voltage Relay & Timer

Subject:

4.16 kV Bus FLUR & SLUR Setpoint and Tech Spec Basis Calculation Computer/Electronic Calculation:

DYES IZI NO Computer 10 Application Name and Version Date of Latest InstaliationNalidation Test Calculation Page Index Calculation Package Contains pages No. of pages Cover Sheet 1 1 Record of revisions 2 1 Calculation checklist 3 to 5 3 Calculation body Pages 6 to 78 73 Attachments Pages 79 to 152 74 Appendices Other: .. TOTAL 152 .. 9000041128 (357S) Rev 1.doc 0622.1450 DCPP Form 69-21457 (04/07/10)

Design Calculation Record of Revisions Rev Status Pages Reason for Revision Prepared LBIE LBIE No.1 affected (Requesting By AD/ Eval Ver. Document No.) Screen No.

J

." ", '" -C, Initials/

Yes/ Yes/

,:: LAN 10/ No/ No/NA I" "0;, -':: > Date NA ' ... -... " I 0 S ALL This calculation supports [x] Yes [ ]Yes resolution of notification HAM8 [ ] No [ ] No 50301 J 67 and DDP I *429 for 5/6/11 [ ] N/A [X] N/A repJacing FLURISLUR relays and establishing new setpoints and Tech Specs , This calc supersedes calculation 357R. 1 P ALL Revision 1 fixes the typo on HAM8 [x] Yes [ ]Yes Page 16. Time delay setpoint 6/22/11 [ ] No [ ] No for TIA relays was incorrectly [ ] N/A [X] N/A entered as 7 seconds. Correct value is 8 seconds. I

  • Check Method: A. :> 9000041128 (357S) Rev 1.doc 0622.1450

... -.----------. -_._-----... -*.. ---._------_......

.. .--.*. ---..... -._._----.... -----.-.--

SAP Calculation No.: Legacy No.: Check LBIE Evaluation Checked Supervisor Method* Approval , PSRC PSRC Initials/

Initials/

Mtg Mtg LAN 10/ LAN 10/

No. Date Date Date " :/ -' [X]A [ ] B AXMO PLJ6 [ ]C [X]A AXMO PLJ6 [ ] B 6/23) " [ ]C C = Critical Point Check B. Insert stamp directing to the PE stamp or seal: -.-. ---------...

CF3.1D 4 Att ac hm e nt 5 Page 2 of 152 9000041128-001 357S-DC Rev 1 Registe r ed Owner's Professional Acceptance Enginee r per CF3.ID17 Signatu r e/ Initials/

LAN 10/ LAN 1 0/ Date Date HAM8 HAM8 b/2.-',/ I ;zf ._--I Page 3 of 152 Item to Verify Complete (enter N/A if not applicable)

Preparer Checker Lan 10 Lan 10 Correct calculation number taken out in SAP -document number, part number, version HAM 8 /f"ft¥10 number. Originating document is entered in SAP as superior document (e.g., OCP number) and/or HAM 8 ,/J.'f...MO on Object Links tab (notification number). , c*

3'{" Cover Page

  • . ;§. ";" Calculation number reflects SAP number and Legacy number. HAM 8 frY.MO Unit number is entered frX,NJO Subject clearly stated. HAM 8 /I-'></VIO If computer calculation , computer/application/validation information filled in. HAM 8 !fy../V\o Calculation Page Index completed. HAM 8 fi.)<jVlO "->;'1:
  • Record of Revisions Page &;. ' ;, ' ... -')I" ,'" . I;I'*-

Rev No., revised pages and reason for revision clearly identified.

HAM 8 /f)<.1Y10 Status matches status in SAP (except if it is PI in SAP, status is F here). HAM 8 If X/YlO Prepared by, checked by and registered professional engineer blocks signed HAM 8 fi)C..MO (full Signature).

CF3.1017 block signed if contractor-completed calc.

NA PE stamp block completed. HAM 8 A.XMO Calculation Body .,*Y', ' .' e>' " " .. . . "",

' . Purpose is clear and includes the requesting document reference (e.g., OCP No). HAM 8 .A-X/Y10 Background is established clearly so that the reader can understand the situation HAM 8 ,A-XJYl 0 without going back to the author. Assumptions are validated or clearly indicated "Preliminary" if verification is required.

HAM 8 A'VV1O If preliminary, SAP Notification No.: SAPO 68012804 operation 150 Inputs validated or clearly indicated "Preliminary" if verification is required.

HAM 8 /1-)C.;V)O If preliminary, SAP Notification No.: As-built configuration is verified as required (steps 5.3.2d.7 and 5.3.2d.9).

NA Nit Methodology described is concise and clear. HAM 8 /t-x./Vl 0 Accepfance criteria provided are clear. HAM 8 ;4-)<;Y10 Body of the calculation is clear so that another person can understand the analysiS HAM 8 (J-.X,M 0 and the logic without going back to the author. Results provides a precise solution to the stated purpose. HAM 8 ,4.)(/V) () 9000041128 (357S) Rev 1.doc 0622.1450 Page 4 of 152 Item to Verify Complete (enter N/A if not applicable)

Preparer Checker LanlD Lan ID Margin assessment includes affect on existing margin (quantitative) or a quali tative HAMS ;4-X/Y? 0 assessment.

Margin data recorded using SRM module NA Nit Conclusion includes applicability and limitations. HAMS ,+X,MO Impact on other documents is performed (step 5.3.2k). HAM 8 A-X,IVlO References are clearly identified as input, output and other references. HAM 8 ,A-XMo Attachments include references not readily retrievable.

HAM 8 1T-)(,'VlO All revised pages have the correct calc no, revision/version number (9*xxxx-yyy-zz).

HAM 8 A--X fr1 c) LBIE AD/Screen completed.

HAM 8 /'}..-X JV\D LBIE evaluation completed, when necessary. NA /'1,4 Calculation input and output references correctly entered in SAP on Calculation record HAM 8 !t-)<MD Object Links tab. Verification __

.. ; . %:: ..

-, ,;'ij*r

t. "'iF Check method A -Independent Review Of Calculation . . . : A<<MO Check method B -Alternate Calculation \/

'" ;

"':j. "I I!; . .'

-';l I'> ,' . .,.,,' ".",'.",;., '.,
  • Comparison to a sufficient number of simplified calculations to support the ,*,,10. , .. calculation.
  • Comparison to an analysis by an alternate verified method. i f I';,',..

Comparison to a similar verified calculation. "

  • I',' 'W.," , :!;,', ' ".::'
  • Comparison to test results.

'j * . .1'. "'>>'x*,

  • Comparison to measured and documented plant data for a comparable design.

.. " .;. ,,' :;t*;: Comparison to published data and correlation confirmed by industry experience.

' .. "',' '.' *

...

-;",

  • Other (describe)

I f;."

Check method C -Critical Point Check "\:.,",:'.

\V Approval:

I"'

,. , \"S'
  • 6-. , .; , .. , * ":"':'.'r:

.,' Operations concurrence documented for any operator action(s).

NA N/+ Eng director approval to issue design with calc in "Preliminary" status. NA flit-Ref.: Calc Approved/Preliminary has a tracking operation off the closure order and is included HAM 8 A"!-fVlO on design engineering review requirements. No.: SAPO 68012804 operation 150 PSRC approval if LBIE evaluation is required , NA ' " : ,;1' ,>:;;0 , ' " PE stamp current for person signing as PE. HAM 8 , ll }tfi.if; . " ... Approve as Final. NA '

"",;,

f.1I 9000041128 (357S) Rev 1.doc 0622.1450 Page 5 of 152 Item to Verify Processing Approved Calc: Calc status updated in SAP. Calc Approved/Pending implementation has a tracking operation off the closure order. Working copy of Approved Calculation package is transmitted to document services for filing in Library or if it is not stored in Library. returned to designated storage location.

Copy of the approved revision transmitted to engineering department clerk for transmitting to RMS. 9000041128 (357S) Rev 1.doc 0622.1450 Complete (enter N/A if not applicable)

Preparer Lan ID Checker LanlD CALCULATION NUMBER: 9000041128 REVISION:

1 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 Section PAGE 6 OF 152 Page 1 Purpose ................................................................................................................................................

10 2 Background

..........................................................................................................................................

11 3 Assumptions

........................................................................................................................................

17 4 Inputs ....................................................................................................................................................

18 5 Methodology

........................................................................................................................................

20 5.1 Channel Uncertainty (CU) Methodology

.......................................................................................

20 5.2 Coincident Logic Considerations (Dropout)

............................................................................

21 5.3 One out of two logic considerations (Pickup) ..........................................................................

21 6 Acceptance Criteria .............................................................................................................................

22 6.1 FLUR Acceptance Criteria ..........................................................................................................

22 6.2 SLUR Acceptance Criteria ..........................................................................................................

22 7 Body of Calculation

.............................................................................................................................

24 7.1 Potential Transformer Ratio Correction Factor (RCF) .............................................................

24 7.2 8ias (8) .........................................................................................................................................

24 7.3 Rack Calibration Accuracy (RCA) .................................................................................................

25 7.3.1 RCA -27H*82 Undervoltage Function ......................................................................................

25 7.3.2 RCA -27H*82 Time Delay Function .........................................................................................

25 7.3.3 RCA -27H*T1A Undervoltage Function ....................................................................................

25 7.3.4 RCA -27H*T1 8 Undervoltage Function ....................................................................................

26 7.3.5 RCA -27H*T1 C Undervoltage Function ....................................................................................

26 7.3.6 RCA -27H*T1A Time Delay Function .......................................................................................

26 7.3.7 RCA -27H*T1 8 Time Delay Function .......................................................................................

27 7.3.8 RCA -27H*T1C Time Delay Function .......................................................................................

27 7.3.9 RCA -27H*T2 Undervoltage Function ......................................................................................

27 7.3.10 RCA -27H*T2 Time Delay Function .....................................................................................

28 7.3.11 RCA -27H*83 Undervoltage Function ..................................................................................

28 7.3.12 RCA -27H*83 Time Delay Function .....................................................................................

28 7.3.13 RCA -27H*84 Undervoltage Function ..................................................................................

29 7.3.14 RCA -27H*84 Time Delay Function .....................................................................................

29 7.3.15 RCA -62H*3A Time Delay Function .....................................................................................

29 7.3.16 RCA -62H*38 Time Delay Function .....................................................................................

29 7.4 Rack Measurement

& Test Equipment Effect (RMTE) ..................................................................

31 7.4.1 RMTE -27H*82 Undervoltage Function ...................................................................................

31 7.4.2 RMTE -27H*82 Time Delay Function .......................................................................................

31 7.4.3 RMTE -27H*T1A Undervoltage Function .................................................................................

31 7.4.4 RMTE -27H*T1 8 Undervoltage Function .................................................................................

31 7.4.5 RMTE -27H*T1 C Undervoltage Function .................................................................................

31 7.4.6 RMTE -27H*T1A Time Delay Function ....................................................................................

31 7.4.7 RMTE -27H*T1 8 Time Delay Function ....................................................................................

32 7.4.8 RMTE -27H*T1C Time Delay Function ....................................................................................

32 7.4.9 RMTE -27H*T2 Undervoltage Function ....................................................................................

32 7.4.10 RMTE -27H*T2 Time Delay Function ...................................................................................

32 7.4.11 RMTE -27H*83 Undervoltage Function ...............................................................................

32 7.4.12 RMTE -27H*83 Time Delay Function ...................................................................................

32 7.4.13 RMTE -27H*84 Undervoltage Function ...............................................................................

32 7.4.14 RMTE -27H*84 Time Delay Function ...................................................................................

32 7.4.15 RMTE -62H*3A Time Delay Function ..................................................................................

33 7.4.16 RMTE -62H*38 Time Delay Function ..................................................................................

33 File Name: 9000041128 (357S) Rev 1.doc 6/22/2011 CALCULATION NUMBER: 9000041128 REVISION:

1 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 PAGE 7 OF 152 7.5 Rack Drift (RD) ..............................................................................................................................

34 7.5.1 RD -27H*82 Undervoltage Function ........................................................................................

34 7.5.2 RD -27H*82 Time Delay Function ............................................................................................

34 7.5.3 RD -27H*T1A Undervoltage Function ......................................................................................

34 7.5.4 RD -27H*T1A Time Delay Function .........................................................................................

34 7.5.5 RD -27H*T1 8 Undervoltage Function ......................................................................................

34 7.5.6 RD -27H*T1 8 Time Delay Function .........................................................................................

34 7.5.7 RD -27H*T1C Undervoltage Function ......................................................................................

34 7.5.8 RD -27H*T1 C Time Delay Function .........................................................................................

34 7.5.9 RD -27H*T2 Undervoltage Function .........................................................................................

34 7.5.10 RD -27H*T2 Time Delay Function ........................................................................................

34 7.5.11 RD -27H*83 Undervoltage Function ....................................................................................

34 7.5.12 RD -27H*83 Time Delay Function ........................................................................................

34 7.5.13 RD -27H*84 Undervoltage Function ....................................................................................

34 7.5.14 RD -27H*84 Time Delay Function ........................................................................................

35 7.5.15 RD -62H*3A Time Delay Function ........................................................................................

35 7.5.16 RD -62H*38 Time Delay Function ........................................................................................

35 7.6 Rack Temperature Effect (RTE) ....................................................................................................

36 7.6.1 RTE -27H*82 Undervoltage Function ......................................................................................

36 7.6.2 RTE -27H*82 Time Delay Function ..........................................................................................

36 7.6.3 RTE -27H*T1A Undervoltage Function ....................................................................................

36 7.6.4 RTE -27H*T1 8 Undervoltage Function ....................................................................................

36 7.6.5 RTE -27H*T1 C Undervoltage Function ....................................................................................

36 7.6.6 RTE -27H*T1A Time Delay Function ......................................................................................

36 7.6.7 RTE -27H*T1 8 Time Delay Function ......................................................................................

36 7.6.8 RTE -27H*T1 C Time Delay Function .......................................................................................

36 7.6.9 RTE -27H*T2 Undervoltage Function .......................................................................................

37 7.6.10 RTE -27H*T2 Time Delay Function ......................................................................................

37 7.6.11 RTE -27H*83 Undervoltage Function ..................................................................................

37 7.6.12 RTE -27H*83 Time Delay Function ......................................................................................

37 7.6.13 RTE -27H*84 Undervoltage Function ..................................................................................

37 7.6.14 RTE -27H*84 Time Delay Function ......................................................................................

37 7.6.15 RTE -62H*3A Time Delay Function .....................................................................................

37 7.6.16 RTE -62H*38 Time Delay Function .....................................................................................

37 7.7 Rack Miscellaneous Effects (RME) ...............................................................................................

38 7.7.1 RME -27H*T1A Undervoltage Function ...................................................................................

38 7.7.2 RME -27H*T1 8 Undervoltage Function ...................................................................................

38 7.7.3 RME -27H*T1 C Undervoltage Function ...................................................................................

38 7.7.4 RME -27H*T1A Time Delay Function .......................................................................................

38 7.7.5 RME -27H*T1 8 Time Delay Function .......................................................................................

38 7.7.6 RME -27H*T1C Time Delay Function ......................................................................................

38 7.7.7 RME -27H*T2 Undervoltage Function ......................................................................................

38 7.7.8 RME -27H*T2 Time Delay Function .........................................................................................

38 7.7.9 RME -27H*83 Undervoltage Function ......................................................................................

39 7.7.10 RME -27H*83 Time Delay Function .....................................................................................

39 7.7.11 RME -27H*84 Undervoltage Function ..................................................................................

39 7.7.12 RME -27H*84 Time Delay Function .....................................................................................

39 7.7.13 RME -62H*3A Time Delay Function ....................................................................................

39 7.7.14 RME -62H*38 Time Delay Function ....................................................................................

39 7.8 Device Level Uncertainty

..............................................................................................................

40 File Name: 9000041128 (357S) Rev 1.doc 6/22/2011 CALCULATION NUMBER: 9000041128 REVISION:

1 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 PAGE 8 OF 152 7.8.1 27H*B2 Undervoltage Actuation Uncertainty

-CU 27H*B2 ........................................................

.40 7.8.2 27H*B2 Time Delay Uncertainty

-

...........................................................................

.40 7.8.3 27H*T1A Actuation Uncertainty

-CU 27H*TlA ...........................................................................

.40 7.8.4 27H*T1 B Actuation Uncertainty

-CU 27H*TlB ...........................................................................

.40 7.8.5 27H*T1C Actuation Uncertainty

-CU 27H*TlC ...........................................................................

.41 7.8.6 27H*T1A Time Delay Uncertainty

-

........................................................................

.41 7.8.7 27H*T1 B Time Delay Uncertainty

-

........................................................................

.41 7.8.8 27H*T1 C Time Delay Uncertainty

-

.......................................................................

.41 7.8.9 27H*T2 Actuation Uncertainty

-CU 27H*T2 ...............................................................................

.41 7.8.10 27H*T2 Time Delay Uncertainty

-

.......................................................................

.41 7.8.11 27H*B3 Actuation Uncertainty-CU 27H*B3 ..........................................................................

.41 7.8.12 27H*B3 Time Delay Uncertainty

-

.......................................................................

.42 7.8.13 27H*84 Actuation Uncertainty

-CU 27H*B4 ..........................................................................

.42 7.8.14 27H*84 Time Delay Uncertainty

-

.......................................................................

.42 7.8.15 62H*3A Time Delay Uncertainty

-

.......................................................................

.42 7.8.16 62H*38 Time Delay Uncertainty

-

.......................................................................

.42 7.9 FLUR 2/2 Logic Undervoltage Load Shed Dropout Uncertainty (CUFLUR_DO)

...............................

.43 7.10 SLUR 2/2 Logic Dropout Uncertainty (CUSLUR_DO)

........................................................................

.43 7.11 Analytical Limits (AL) ....................................................................................................................

.45 7.11.1 27H*T1A (Time Delayed) .....................................................................................................

.45 7.11.2 27H*T18 (Time Delayed) .....................................................................................................

.45 7.11.3 27H*T1 C (Time Delayed) .....................................................................................................

.45 7.11.4 27H*T2 (Instantaneous)

.......................................................................................................

.45 7.11.5 27H*B2 (Time Delayed) .......................................................................................................

.45 7.11.6 27H*83 & 84 (Initiate Timer) ................................................................................................

.45 7.11.7 62H*3A (Timer) .....................................................................................................................

45 7.11.8 62H*38 (Timer) .....................................................................................................................

46 7.12 Determination of Setpoint Limits and Acceptable As-Found Settings ..........................................

.47 7.12.1 27H*82 Undervoltage Setpoint Limit (Low Voltage) .............................................................

.47 7.12.2 27H*B2 Undervoltage Setpoint Limit (Low-Low Voltage) .....................................................

.47 7.12.3 27H*82 Undervoltage Setpoint Limit (Loss of Voltage) .........................................................

48 7.12.4 27H*B2 Time Delay Setpoint Limit (Low Voltage) ................................................................

.48 7.12.5 27H*B2 Time Delay Setpoint Limit (Loss of Voltage) ...........................................................

.48 7.12.6 27H*B2 Undervoltage Acceptable As-Found (AAF) Determination

.....................................

.49 7.12.7 27H*B2 Time Delay Acceptable As-Found (AAF) Determination

..........................................

50 7.12.8 27H*T1A Undervoltage Setpoint Limit (Low Voltage) ...........................................................

51 7.12.9 27H*T1 B Undervoltage Setpoint Limit (Low Voltage) ...........................................................

51 7.12.10 27H*T1C Undervoltage Setpoint Limit (Low Voltage) ...........................................................

51 7.12.11 27H*T1A Undervoltage Acceptable As-Found (AAF) Determination

....................................

52 7.12.12 27H*T1 B Undervoltage Acceptable As-Found (AAF) Determination

....................................

52 7.12.13 27H*T1 C Undervoltage Acceptable As-Found (AAF) Determination

....................................

52 7.12.14 27H*T1A Time Delay Setpoint Limit (Low Voltage) ...............................................................

52 7.12.15 27H*T1B Time Delay Setpoint Limit (Low-Low Voltage) .......................................................

53 File Name: 9000041128 (357S) Rev 1.doc 6/22/2011 CALCULATION NUMBER: 9000041128 REVISION:

1 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 PAGE 9 OF 152 7.12.16 27H*T1 C Time Delay Setpoint Limit (Loss of Voltage) .........................................................

53 7.12.17 27H*T1A Time Delay Acceptable As-Found (AAF) Determination

.......................................

53 7.12.18 27H*T18 Time Delay Acceptable As-Found (AAF) Determination

.......................................

53 7.12.19 27H*T1 C Time Delay Acceptable As-Found (AAF) Determination

.......................................

54 7.12.20 27H*T2 Undervoltage Setpoint Limit (Instantaneous)

...........................................................

54 7.12.21 27H*T2 Undervoltage Acceptable As-Found (AAF) Determination

.......................................

54 7.12.22 27H*83 Undervoltage Setpoint Limit (Low Voltage) ..............................................................

54 7.12.23 27H*83 Undervoltage Acceptable As-Found (AAF) Determination

......................................

55 7.12.24 27H*84 Undervoltage Setpoint Limit (Low Voltage) ..............................................................

55 7.12.25 27H*84 Undervoltage Acceptable As-Found (AAF) Determination

......................................

55 7.12.26 62H*3A Time Delay Setpoint Limit ........................................................................................

56 7.12.27 62H*3A Time Delay Acceptable As-Found (AAF) Determination

..........................................

56 7.12.28 62H*38 Time Delay Setpoint Limit ........................................................................................

56 7.12.29 62H*38 Time Delay Acceptable As-Found (AAF) Determination

..........................................

56 7.12.30 SLUR Dropout Avoidance Limit.. ...........................................................................................

58 7.13 Maximum Pickup Voltage (Reset) .................................................................................................

60 7.13.1 27H*82 Diesel Start Reset ....................................................................................................

60 7.13.2 27H*T1 & 27H*T2 Load Shed Reset. ....................................................................................

62 7.13.3 SLUR Diesel Start & Load Shed Reset .................................................................................

63 8 Results ..................................................................................................................................................

65 9 Margin Assessment

.............................................................................................................................

73 10 Conclusion

...........................................................................................................................................

74 11 Impact Evaluation

................................................................................................................................

75 12 References

...........................................................................................................................................

76 12.1 Input References

...........................................................................................................................

76 12.2 Output References

........................................................................................................................

77 12.3 Other References

..........................................................................................................................

77 13 Enclosures and Attachments

.............................................................................................................

78 File Name: 9000041128 (357S) Rev 1.doc 6/22/2011 CALCULATION NUMBER: 9000041128 REVISION:

1 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011

1. Purpose PAGE 10 OF 152 This calculation establishes the basis for technical specifications and setpoints of the vital 4kV busses' First Level Undervoltage Relays and Second Level Undervoltage Relays (referred to as FLUR and SLUR respectively throughout this calculation).

This calculation supports the resolution of notification 50301167 and the replacement of the Unit 1 and Unit 2 First Level and Second Level Undervoltage Relays (FLUR and SLUR). A licence amendment request will be submitted to the NRC requesting approval for replacing the FLUR's and SLUR's with models of greater accuracy and for re-designing the relay logic to address outstanding concerns over the adequacy of the equipment protection provided by the FLUR's and SLUR's. The First Level Undervoltage Protection consists of the 27HxB2 (Transfer to startup & diesel start) relays, the 27HxT1 (Time Delay Load Shed) relay and the 27HxT2 (Instantaneous Load Shed permissive) relay. The subject modification will change the make and model for the FLUR Instantaneous Load Shed Relay (27HxT2) and the FLUR Time Delay Load Shed Relay (27HxT1).

The FLUR Time Delay Load Shed Relay will now be made up of 3 independent relays for each bus (27HxT1A, 27HxT1 B, 27HxT1 C). Each relay will initiate load shed timing at different levels of voltage degradation on the bus (LOW VOLTAGE, LOW-LOW VOLTAGE & LOSS OF VOLTAGE) respectively.

The FLUR relay responsible for transfer to startup and diesel start (27HxB2) will not be modified, however its tech spec and setpoint basis are included as part of this calculation.

For the 27H*B2 relays, the pickup setpoint is not adjustable and it is a function of dropout. This calculation also provides an analysis of relay performance of the 27H*B2 relays based on recent calibration data. The Second Level Undervoltage (Voltage Sensing) Relays and their associated timers will also be replaced with more accurate models. The setpoints will be changed to enhance equipment protection and optimize availability of offsite power. The Tech Spec limits for the SLUR setpoints will not be changed. Throughout this document, the under-voltage setpoint activated due to drop in the bus voltage is referred to as "dropout setpoint" and the reset activated due to rise in bus voltage is referred to as "pickup setpoint".

This calculation also computes the burden on each potential transformer that reduces the 4kV bus voltage to .... 120VAC measurable signal. The following devices are within the scope of this calculation:

Table 1.1 FLOC Description Make Model Location DC-1I2-63-E-XF-SHF(G,H)12PT Potential Transformer GE JVM-3 A-119 DC-1I2-63-E-R-27HF(G,H)B3 SLUR Relay ABB 59N A-119 DC-1I2-63-E-R-27HF(G,H)B4 SLUR Relay ABB 59N A-119 DC-1I2-63-E-R-62HF(G,H)3A SLUR Timer (EDG Start) ABB 62T A-119 DC-1I2-63-E-R-62HF(G,H)3B SLUR Timer (EDG Start) ABB 62T A-119 DC-1I2-63-E-R-27HF(G,H)TIA FLUR (Time Delayed Load Shed ABB 27N A-119 LOW VOLTAGE) DC-1I2-63-E-R-27HF(G,H)TIB FLUR (Time Delayed Load Shed ABB 27N A-119 LOW-LOW VOLTAGE) DC-1I2-63-E-R-27HF(G,H)Tl C FLUR (Time Delayed Load Shed ABB 27N A-119 LOSS OF VOLTAGE) DC-1I2-63-E-R-27HF(G,H)T2 FLUR (Instantaneous Load Shed) ABB 59N A-119 File Name: 9000041128 (357S) Rev 1.doc 6/22/2011 CALCULATION NUMB E R: 9000 0411 28 R E VISION: 1 PAG E 11 O F 152 C A L CULATION T ITL E: 4.1 6 kV B us F LUR & S LU R Se tp o int Ca l c ul at ion DA TE: 03/2 2/2 011 FLOC Descr i pt i on Make Mode l Locat i on D C-1I 2-6 3-E-R-2 7 HF (G ,H)B 2 FLUR (E DG S t art on L o w , Low-L o w Bas le r B E I-GPS A-119 & Loss of Voltage) 2. Background Per FSAR Section 8.3.1.1.8.2, the DCPP emergency electrical power system including each vital bus and its control protection, and instrumentation was originally designed in accordance with IEEE Standards 308-1971 and 279-1971.

These standards required loss of voltage detection and initiation of protection signals which were implemented via a first level of undervoltage protection.

The original design function of this first level of undervoltage protection was detection and recovery of loss of voltage. PG&E received additional requirements for a second level of undervoltage protection relays in a letter from the NRC dated November 22, 1977. These requirements were reflected in DCPP SSER 9. The following discussion defines each criteria and how it is satisfied by the FLURISLUR relays or a DCPP calculation or analysis.

(1) We require that a second level of voltage protection for the onsite power system be provided and that this second level of voltage protection shall satisfy the following requirements:

a) The selection of voltage and time set points shall be determined from an analysis of the voltage requirements of the safety-related loads at all onsite steam distribution levels;

  • Voltage studies have been performed of vital 4kV motor starting and steady state loading to determine motor protective device trip times and adequacy in calculation 170-DC [ref. 12.1.58]. These trip times have been considered in establishing FLUR and SLUR load shed setpoints.
  • Voltage studies have been performed of vital 480VAC loads for starting and steady state to determine motor protective device trip times and adequacy in calculation 9000041185

[ref. 12.1.59]. These trip times have been considered in establishing FLUR and SLUR load shed setpoings.

  • Voltage studies have been performed of vital loads fed at each vital power distribution level by fuses in calculation 9000041186

[ref. 12.1.60]. Impacts of degraded voltage on vital loads fed by fuses have been considred in establish i ng FLUR and SLUR load shed setpoints. b) The voltage protection shall include coincidence logic to preclude spurious trips of the offsite power source;

  • The FLUR relays require a 2 out of 2 coincident logic in order to load shed the vital 4kV busses.

c) The time delay selection shall be based on the following conditions: (i) The allowable time delay, including margin, shall not exceed the maximum time delay that is assumed in the FSAR accident analyses; File Name: 9000041128 (357S) Rev 1.doc 6/22/2011 CALCULATION NUMBER: 9000041128 REVISION:

1 PAGE 12 OF 152 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 CD Per Notification 50301167 Task 18 and Design Input Transmittal 50301167 0, Westinghouse has evaluated the impact of the maximum SLUR load shed time delay on the DCPP safety analyses.

This calculation ensures that all relay actuations (including setpoint and uncertainty) occur within the 20 second SLUR load shed Tech Spec limit assumed in the safety analyses. (ii) The time delay shall minimize the effect of short duration disturbances from reducing the availability of the offsite power source(s);

  • The adequacy of the SLUR and FLUR relay time delays and their impact on the availability of the offsite power source is evaluated in calculation 359-DC. (iii) The allowable time duration of a degraded voltage condition at all distribution system levels shall not result in failure of safety systems or components;
  • Calculation 170-DC [ref. 12.2.10] will take the voltage and time setpoints for the FLUR and SLUR relays and determine adequacy of motor protection for vital 4kV loads.
  • Calculation 9000041185

[ref. 12.2.11] will take the voltage and time setpoints for the FLUR and SLUR relays and determine adequacy of load protection for vital 480VAC loads.

  • Calculation 9000041186

[ref. 12.1.60] will take setpoints from this calculation and determine adequacy of load protection for loads fed by vital fuses. (iv) The voltage sensors shall automatically initiate the disconnection of offsite power sources whenever the voltage set point and time delay limits have been exceeded; The following description of the FLUR and SLUR relay functions describe the automatic actions of these relays. The first level under-voltage protection relays (FLUR) detect the degraded and the loss of voltage conditions on the vital 4.16Kv busses. The first level under-voltage protection relays are made up of 5 different relays each with its own voltage sensing setpoint and time delay. The 27HxB2 relay is a microprocessor based relay with a three step voltage vs time profile. This relay is responsible for initiating the transfer to start up and diesel generator start signals when its voltage and time setpoints are met. After a sufficient time delay they allow the transfer of vital busses to the startup transformer.

Diesel generators are automatically started on sustained bus voltage. The 27HxT1 A, Band C relays provide a three tier voltage vs. time profile for load shedding the vital 4kV bus. The 27HxT1A detects low vital bus voltage, the 27HxT1 B detects low-low vital bus voltage and the 27HxT1 C detects loss of vital File Name: 9000041128 (3578) Rev 1.doc 6/22/2011 CALCULATION NUMBER: 9000041128 REVISION:

1 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 PAGE 13 OF 152 bus voltage. The time delay associated with each "T1" relay decreases with lower bus voltage setpoint.

The 27HxT2 relay is an instantaneous relay with one voltage setpoint.

The function of the "T2" relay is to provide coincidence logic to preclude spurious trips of the offsite power sources. Actuation of either of the three "T1" relays and the "T2" relay will load shed the respective vital 4.16Kv bus. If the transfer to the Startup Transformer is unsuccessful, the FLURs will shed the vital bus motor loads. Diesel breaker closing is time delayed approximately 2.seconds to allow the motor breakers to trip and bus voltage to decay. After the diesel generator breaker closes, the vital bus will be loaded in a predetermined sequence.

The second level undervoltage relays (SLUR) detect bus voltage approaching the 3785V limit (approximately 900/0 of bus voltage) and provide diesel generator start and vital 4.16kV bus load shed signals. The 3785V setting is based on NRC second level undervoltage relay setting requirements

[Ref. 12.1.12, page 43]. The second level under-voltage protection relays are made up of 4 different relays each with its own voltage sensing setpoint and time delay. The 27HxB3 relay is a solid state near instantaneous relay with one voltage setpoint.

Similarly the 27HxB4 relay is also a solid state near instantaneous relay with one voltage setpoint.

Together these relays provide undervoltage protection and two out of two coincidence logic is required to preclude spurious trips of the offsite power sources. When the coincidence logic is made up, the undervoltage signal initiates two separate timing relays 62Hx3A and 62Hx3B. The 62Hx3A relay initiates diesel start after a maximum time delay of 10 seconds. This maximum time delay for diesel starts is accounted for in DCPP's accident analyses.

The 62Hx3B relay initiates vital 4.16kV bus load shed after a maximum time delay of 20 seconds. The maximum time delay of 20 seconds is based on allowed short time overheating of motors due to undervoltage.

This time is based on motor manufacturer's maximum motor starting time of 20 seconds [Ref. 12.1.12]. (v) The voltage sensors shall be designed to satisfy the applicable requirements of IEEE Std. 279-1971, "Criteria for Protection Systems for Nuclear Power Generating Stations;" and

  • Per FSAR Section 8.3.1.1.8.2, the DCPP emergency electrical power system including each vital bus and its control protection, and instrumentation was originally designed in accordance with IEEE Standards 308-1971 and 279-1971. File Name: 9000041128 (357S) Rev 1.doc 6/22/2011 CALCULATION NUMBER: 9000041128 REVISION:

1 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 PAGE 14 OF 152 (vi) The Technical Specification shall include limiting condition for operation, surveillance requirements, trip setpoints with minimum and maximum limits, and allowable values for the second-level voltage protection sensors and associated time delay devices.

  • OCPP TS 3.3.5.3 provides a minimum voltage value for the FLUR and SLUR TS limits. Calculation 357S-0C establishes the technical specification bases, TS minimum voltage and maximum time delay limits and allowable maximum and minimum as-found values for the FLURISLUR calibration acceptance criteria.

NUREG-1431 provides a minimum and maximum voltage value for the FLUR and SLUR TS limits. OCPP technical specifications have never had maximum limits for the FLURISLUR voltage sensing trip setpoints.

A maximum setpoint would be non-conservative in that it would reduce the margin available for offsite power availability.

The configuration at OCPP was approved in SSER 9. Additionally, a review of industry technical specifications concluded that the following plants provide only a minimum voltage value for the FLUR and SLUR TS limits: Catawba Units 1 and 2, Braidwood Units 1 and 2, Beaver Valley Units 1 and 2, Millstone Unit 3, McGuire Units 1 and 2, Indian Point Unit 3, Point Beach Units 1 and 2, Salem Unit 1, Seabrook Unit 1, Sequoyah Unit 1, South Texas Units 1 and 2, Summer Unit 1, Vogtle Units 1 and 2, and Wolf Creek Unit 1. File Name: 9000041128 (3578) Rev 1.doc 6/22/2011 CALCULATION NUMBER: 9000041128 REVISION:

1 PAGE 15 OF 152 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 BLOCK DIAGRAM: 62H*3A The following 27H*B3 -C (Tech Spec Limit: 3785VAC < 10 Sec SR 3. 3. 5. 3. b) Percent of simplified block diagram depicts the function of each relay and the analytical limits associated with voltage dropout and time delay settings.

Tables 2.1 & 2.2 summarize the setpoint of each device and provides analytical limits as referenced on the block diagram. 2/2 Diesel Start "----"1<:-11+--1....

Load Shed (Tech Spec Limit: 3785VAC < 20 Sec SR 3.3.5.3.b) 62H*3B 27H*T2 { (Analytical Limit: 3411 VAC) -Load (Analytical Limit: 3328 VAC < 10 Sec) 27H*TIA Limit: 3120 VAC < 6 Sec) 27H*TIB .---....... Shed 2/2 (Analytical Limit: 2704 VAC < 4 Sec) 27H*TIC D Transfer to SU & Diesel --""t:-fS1++---------t

.... Start 27H*B2 ("LOW Voltage" Tech Spec Limit: 2583VAC < 10 Sec SR 3. 3. 5. 3. a) ("LOW-LOW Voltage" Nominal Setpoint:

1070VAC < 1.9 Sec) ("LOSS of Voltage" Tech Spec Limit: OVAC < 0.8 Sec SR 3.3.5.3.a)

File Name: 9000041128 (357S) Rev 1.doc Bus Voltage 91% 91% 82% 80% 75% 65% 6/22/2011 I I I CALCULATION NUMBER: 9000041128 REVISION:

1 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 PAGE 16 OF 152 Table 2.1, FLUR & SLUR Setpoint Summary Undervoltage PT Bus Equivalent Time Delay Device Setpoint Analytical Limit (VAC) Ratio* Voltage Setpoint (Sec) 27P: 76.3 27P:2667 27P: 4.7 27P: 2583V @ < 10 sec 1-27HFB2 127P: 30.6 34.951 127P: 1070 127P: 1.9 127P: NA 27X: 23.4 27X: 818 27X: 0.65 27X: OV @ < 0.8 sec 27P: 76.3 27P:2667 27P: 4.7 27P: 2583V @ < 10 sec 1-27HGB2 127P: 30.6 34.951 127P: 1070 127P: 1.9 127P: NA 27X: 23.4 27X: 818 27X: 0.65 27X: OV @ < 0.8 sec 27P: 76.3 27P:2667 27P: 4.7 27P: 2583V @ < 10 sec 1-27HHB2 127P: 30.6 34.951 127P: 1070 127P: 1.9 127P: NA 27X: 23.4 27X: 818 27X: 0.65 27X: OV @ < 0.8 sec 1-27HFTIA 96.5 34.951 3373 8 sec 3328V @J < 10 Sec 1-27HGTIA 96.5 34.951 3373 8 sec 3328V @< 10 Sec 1-27HHTlA 96.5 34.951 3373 8 sec 3328V @J < 10 Sec 1-27HFTlB 90.5 34.951 3163 5 sec 3120V @, < 6 Sec 1-27HGTIB 90.5 34.951 3163 5 sec 3120V @ < 6 Sec 1-27HHTIB 90.5 34.951 3163 5 sec 3120V @, < 6 Sec 1-27HFTIC 78.6 34.951 2747 3 sec 2704V @ < 4 Sec 1-27HGTIC 78.6 34.951 2747 3 sec 2704V @J < 4 Sec 1-27HHTIC 78.6 34.951 2747 3 sec 2704V @ < 4 Sec 1-27HFT2 98 35.182 3448 NA 3411V 1-27HGT2 98 35.287 3458 NA 3411V 1-27HHT2 98 35.224 3452 NA 3411V 1-27HFB3 109.25 34.951 3818 See 1-62HF3AIB 3785V @, < 10 sec EDG Start & < 20 Sec Load Shed 1-27HGB3 109.25 34.951 3818 See 1-62HG3AIB 3785V @< 10 sec EDG Start & < 20 Sec Load Shed 1-27HHB3 109.25 34.951 3818 See 1-62HH3AIB 3785V @, < 10 sec EDG Start & < 20 Sec Load Shed 1-27HFB4 109.25 35.182 3844 See 1-62HF3A1B 3785V @ < 10 sec EDG Start & < 20 Sec Load Shed 1-27HGB4 109.25 35.287 3855 See 1-62HG3AIB 3785V @, < 10 sec EDG Start & < 20 Sec Load Shed 1-27HHB4 109.25 35.224 3848 See 1-62HH3AIB 3785V @ < 10 sec EDG Start & < 20 Sec Load Shed 1-62HF3A NA NA NA 8.5 sec <10 sec EDG Start 1-62HG3A NA NA NA 8.5 sec <10 sec EDG Start 1-62HH3A NA NA NA 8.5 sec <10 sec EDG Start 1-62HF3B NA NA NA 18.5 sec <20 sec Load shed 1-62HG3B NA NA NA 18.5 sec <20 sec Load shed 1-62HH3B NA NA NA 18.5 sec <20 sec Load shed 27P: 76.3 27P:2667 27P: 4.7 27P: 2583V @ < 10 sec 2-27HFB2 127P: 30.6 34.951 127P: 1070 127P: 1.9 127P: NA 27X: 23.4 27X: 818 27X: 0.65 27X: OV @ < 0.8 sec 27P: 76.3 27P:2667 27P: 4.7 27P: 2583V @< 10 sec 2-27HGB2 127P: 30.6 34.951 127P: 1070 127P: 1.9 127P: NA 27X: 23.4 27X: 818 27X: 0.65 27X: OV @ < 0.8 sec 27P: 76.3 27P:2667 27P: 4.7 27P: 2583V @< 10 sec 2-27HHB2 127P: 30.6 34.951 127P: 1070 127P: 1.9 127P: NA 27X: 23.4 27X: 818 27X: 0.65 27X: OV @ < 0.8 sec 2-27HFTIA 96.5 34.951 3373 8 sec 3328V @, < 10 Sec 2-27HGTIA 96.5 34.951 3373 8 sec 3328V @< 10 Sec 2-27HHTIA 96.5 34.951 3373 8 sec 3328V @J < 10 Sec 2-27HFTIB 90.5 34.951 3163 5 sec 3120V @ < 6 Sec 2-27HGTIB 90.5 34.951 3163 5 sec 3120V @J< 6 Sec 2-27HHTlB 90.5 34.951 3163 5 sec 3120V @,< 6 Sec 2-27HFTIC 78.6 34.951 2747 3 sec 2704V @ < 4 Sec 2-27HGTIC 78.6 34.951 2747 3 sec 2704V @, < 4 Sec 2-27HHTIC 78.6 34.951 2747 3 sec 2704V @ < 4 Sec 2-27HFT2 98 35.182 3448 NA 3411V 2-27HGT2 98 35.287 3458 NA 3411V 2-27HHT2 98 35.224 3452 NA 3411V 2-27HFB3 109.25 34.951 3818 See 2-62HF3AIB 3785V @ < 10 sec EDG Start & < 20 Sec Load Shed File Name: 9000041128 (357S) Rev 1.doc 6/22/2011 CALCULATION NUMBER: 9000041128 REVISION:

1 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 2-27HGB3 109.25 34.951 3818 See 2-62HG3AIB 2-27HHB3 109.25 34.951 3818 See 2-62HH3AIB 2-27HFB4 109.25 35.182 3843 See 2-62HF3AIB 2-27HGB4 109.25 35.287 3855 See 2-62HG3AIB 2-27HHB4 109.25 35.224 3848 See 2-62HH3AIB 2-62HF3A NA NA NA 8.5 sec 2-62HG3A NA NA NA 8.5 sec 2-62HH3A NA NA NA 8.5 sec 2-62HF3B NA NA NA 18.5 sec 2-62HG3B NA NA NA 18.5 sec 2-62HH3B NA NA NA 18.5 sec

  • PT Ratio is from Attachment "1" 3. Assumptions PAGE 17 OF 152 3785V (jiJ < 10 sec EDG Start & < 20 Sec Load Shed 3785V @ < 10 sec EDG Start & < 20 Sec Load Shed 3785V @ < 10 sec EDG Start & < 20 Sec Load Shed 3785V @ < 10 sec EDG Start & < 20 Sec Load Shed 3785V @ < 10 sec EDG Start & < 20 Sec Load Shed <10 sec EDG Start <10 sec EDG Start <10 sec EDG Start <20 sec Load shed <20 sec Load shed <20 sec Load shed 3.1. The undervoltage relays are located in the turbine building, Area "A" elevation 119' in the 4KV switchgear room [FLOC]. The normal operation profile in this room is specified to be within 39°F(3.9°C) to 104°F(40°C)

[Ref. 12.1.10].

Following a high energy line break, the maximum temperature in the 4KV switchgear room is calculated to be 95.3°F(35.2°C)

[Ref. 12.1.55 & Attachment 7]. Therefore, for the purpose of calculating the temperature effect on these relays the upper limit of 95.3°F(35.2°C) will be used. The OCM T-20 lower temperature limit of 39°F(3.9°C) is based on lowest ambient temperature recorded from 1973 to 1982. Since the 4KV switchgear room is sufficiently isolated from outside environment and the relays are located in cabinets with energized components, it will be assumed that the lowest temperature these switches are exposed to is 50°F(10°C).

The range of extreme temperatures for these switches is 95.3°F(35.2°C)

-50°F(10°C)

= 45.3°F(25.2°F).

3.2. Basler does not specify a temperature effect for the BE1 relays for both the undervoltage and timing functions.

Since the relays are located in a mild environment

[see paragraph 3.1], it will be assumed that relay reference accuracy includes any temperature effect. 3.3. Maintenance Procedure MP E-50.61 [Ref. 12.1.6] was written for the old style 27H*T1 relays Basler BE1-27. The new ABB 27N relays do not have a maintenance procedure yet however it will be assumed that the same measurement and test equipment used to calibrate in MP E-50.61 will be used to calibrate the voltage dropout and pickup functions of the new ABB 27N relays. In addition the ABB 27N relays will have a time delay function that must be calibrated.

It is assumed that the M& TE specified in MP E-50.30B [Ref. 12.1.5] for calibrating the time delay of Agastat ETR relays will be used. 3.4. Maintenance Procedure MP E-50.33A [Ref.12.1.4]

was written for the old style 27H*T2, 27H*B3 and 27H*B4 relays Westinghouse SSV-T. The new ABB 59N relays do not have a maintenance procedure yet. However it will be assumed that the same measurement and test equipment used to calibrate in MP E-50.33A will be used to calibrate the voltage dropout and pickup functions of the new ABB 59N relays. In addition the ABB 59N relays will have a time delay function that must be calibrated.

It is assumed that the M& TE specified in MP E-50.30B [Ref. 12.1.5] for calibrating the time delay of Agastat ETR relays will be used. 3.5. Maintenance Procedure MP E-50.30B [Ref. 12.1.5] was written for the old style 62H*3A and 62H*3B relays Agastat ETR. The new ABB 62T relays do not have a maintenance procedure yet. However it will be assumed that the same measurement and test equipment used to calibrate in MP E-50.30B will be used to calibrate the time delay functions of the new ABB 62T relays. File Name: 9000041128 (357S) Rev 1.doc 6/22/2011 CALCULATION NUMBER: 9000041128 REVISION:

1 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 PAGE 18 OF 152 3.6. The ABB 27N and 59N relays are not currently in use at DCPP. Hence drift data is not available from calibration records. In addition ABB does not publish drift values for these relays. Per CF6.NE1 [reference 12.1.1] Appendix 8.2 Section 2.3 in absence of calibration data and vendor published drift values, the default drift value to be used is +/-20/0 of sensor span. Setpoints for ABB 27N and 59N relays are set using a combination of a fixed tap resistor and a potentiometer which is common for all available taps [reference 12.1.51].

ABB was contacted to provide the setpoint span for each tap setting of these relays. ABB performed limited testing on one ABB 27N relay [reference 12.1.57].

The results support the assumption that the potentiometer allows for setpoint adjustment of -120/0 to +5% of tap setting. Due to the similarity between ABB 27N and 59N relays, a preliminary assumption will be made to apply this setpoint span to both the ABB 27N and 59N relays. This span will be used in calculating the default drift values per CF6.NE1. The assumption will be validated via future testing by the DCPP maintenance department on both the 27N and 59N models to be used at DCPP. This testing is tracked to completion by SAP order 68012804 operation 150 and is required prior to return to service. 3.7. The ABB 27N and 59N relays allow for setting the Dropout (Actuate) setting as a percentage of the Pickup (Reset) setting. This calculation will specify a setpoint for the dropout setting and the pickup will be calculated as a percentage of the dropout setting. Accordingly, this calculation assumes that the uncertainty impacts the dropout setting and that the dropout and pickup settings will drift together in the same direction and not independently of each other. 4. Inputs 4.1. Basler BE1-GPS100 Reference Accuracy for undervoltage function:

+/-2% of reading or +/-1 V whichever is greater [Ref. 12.1.50].

The use of 1 V reference accuracy for the 127P and 27X devices will result in an over conservatism.

Inspection of the historical As-Left calibration data shows that the 127P and 27X devices of these relays have been calibrated well within +/-0.3V and +/-0.2V respectively.

To be conservative but not overly conservative only the +/-2% reference accuracy will be used in this calculation.

4.2. Basler BE1-GPS100 Reference Accuracy for time delay function:

+/-5% or +/-3 cycles whichever is greater [Ref. 12.1.50]. Three cycles translate to 0.05 seconds (3c /60c/S). 4.3. ABB 27N and 59N Reference Accuracy for undervoltage function:

+/-O.1 % of pickup and dropout settings [Ref. 12.1.51].

4.4. ABB 27N and 59N Reference Accuracy for time delay function:

+/-10% or +/-20ms whichever is greater [Ref. 12.1.51].

4.5. ABB 62T timer reference accuracy:

+/-0.50/0 or +/-15ms or +/- 1 digit of setting (whichever is greater) [Ref.12.1.52].

4.6. To calibrate the Basler BE1-GPS100 undervoltage function, an AC Voltmeter, 0-150V range, with accuracy of +/-(0.06% of reading + 0.03% of range) [Ref. 12.1.7] is used. Range of the HP 34401A is 1 to 750 VAC [Attachment 6]. 4.7. To calibrate the ABB 27N, 59N & BE1-GPS100 time delay function, Manta MTS-1710 Advanced Universal Protective Relay Test System is used [Ref. 12.1.6 & 12.1.7]. The accuracy of this test equipment for a 0-9.9999 sec scale is: M& TE = +/-0.5 mSec +/-1 least significant digit = +/-0.0006 sec For all other scales it is: File Name: 9000041128 (357S) Rev 1.doc 6/22/2011 CALCULATION NUMBER: 9000041128 REVISION:

1 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 M& TE = +/-(0.005% of reading +1 digit), 1 digit = 0.1 mS [Attachment 4]. PAGE 19 OF 152 4.8. To calibrate the ABB 27N and 59N undervoltage function an AC Voltmeter, range 0-150 VAC with accuracy of +/-(0.06% of reading + 0.03% of range) is used [Ref. 12.1.6]. Range of the HP 34401A is 1 to 750 VAC [Attachment 5]. 4.9. To calibrate the ABB 62T Timers, it is assumed that similar to the existing calibration procedure, the new calibration procedure

[Ref. 12.1.5] will provide the option of using either a Manta MTS-1710 Advanced Universal Protective Relay Test System or a timer with accuracy of 0.01 % of elapsed time +10 mSec or better. At 8.5 and 18.5 seconds setpoint the accuracy of the specified generic timer is: MTE = +/-(0.01 % X 8.5 + 0.010) = +/-0.011 Sec MTE = +/-(0.01 % X 18.5 + 0.010) = +/-0.012 Sec These values are larger than the Manta test system calculated in section 4.7. For the purpose of conservatism, the uncertainty of a generic timer will be used for the M& TE effect for 62H*3A1B timers. 4.10. The ABB 27N and 59N relays equipped with harmonic filter have a temperature effect of +/-0.4% over a temperature range of 50°F(1 O°C) to 104°F(40°C) (range of 54°F) [reference 12.1.51].

Per paragraph 3.1 it is assumed that the relays are exposed to a temperature range of 45.3°F. Therefore, the temperature effect should be scaled in accordance with reference 12.1.1, Attachment 8.2, section 5.5 as follows: TE = + O.4%x (45.3° F) = 0.33% [54° F] ABB does not specify a temperature effect for the Time Delay function of the 27N and 59N relays. Since the relays are located in a mild environment

[see paragraph 3.1], it will be assumed that relay reference accuracy includes any temperature effect for the time delay function.

4.11. The ABB 62T relays have a temperature effect of +/-2%, +/-20ms or +/-1 digit (which ever is greater) over a temperature range of -4°F(-20°C) to 158°F(70°C) (range of 162°F) [reference 12.1.52].

The 1 digit on a relay with a range of 0.01-9.99 seconds is equal to 10 milliseconds.

On a 0.01 to 99.9 seconds range it is equal to 100 milliseconds.

Per paragraph 3.1 it is assumed that the relays are exposed to a temperature range of 45.3°F. Therefore, the temperature effect should be scaled in accordance with reference 12.1.1, Attachment 8.2, section 5.5 as follows: TE = + 2%x(45.3° F) = 0.6% [1620 F] At 8.5 and 18.5VAC setpoints, the temperature effects are respectively 51 and 111 milliseconds.

4.12. Basler GPS100 Relay: The vendor does not provide any information as to the control voltage effect. But it provides a spec for the 125vdc power supply which is capable to File Name: 9000041128 (3578) Rev 1.doc 6/22/2011 CALCULATION NUMBER: 9000041128 REVISION:

1 PAGE 20 OF 152 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 perform its function for control voltages from 35 to 150 Vdc.[Ref.

12.1.50].

Hence RME term will be 0 for the GPS1 00 Relay. 4.13. ASS 27N and 59N Relay: The vendor datasheet provides a repeat accuracy of 0.1 % over the allowable dc control power range of 100-140 VDC. This value is independent of the manufacturer's reference accuracy.

[Ref. 12.1.51].

ASS does not specify a control power range effect on the time delay feature of these relays. RME term is 0 for time delay. 4.14. ASS 62T: The vendor datasheet provides an accuracy of +/- 2% or +/- 15ms or +/- 1 digit (whichever is greater) over the allowable control power range of -200/0, +10% of the nominal control voltage. [Ref. 12.1.52].

On a device with a range of 0.01 to 9.99 sec, the 1 digit translates to 10 milliseconds.

On a 0.1 to 99.9 seconds range device, the 1 digit translates to 100 milliseconds.

The 2% temperature effect at 8.5 seconds setpoint translates to 170 milliseconds and at a 18.5 seconds setpoint it translates to 370 milliseconds.

5. Methodology The following methodology is used in the determination of FLUR & SLUR Channel Uncertainty (CU), setpoints (STP) and Acceptable As-Found (AAF) values 5.1. Channel Uncertainty (CU) Methodology:

Determination of the relay actuation and time delay uncertainty (CU) is based on the following algorithm provided in Reference 12.1.1. The above equation however is customized for each application as follows: EA: The EA term is associated with the environmental allowance following a design bases accident.

Since, the relays are located in the switchgear room in the fuel handling building and the environmental condition following LOCA and HELS is enveloped by plant normal conditions, the EA term will be removed from the above equation.

PEA: This term is associated with flow metering devices. Therefore it will be removed from the above equation.

seA, so, SMTE, SPE & STE: The relays will be treated as rack components and the uncertainty terms associated with the sensor will be removed. PMA: Since error associated with the measurement of line voltage is treated as bias due to burden effect on the instrument potential transformer, the PMA term will be removed. RME: The only potential miscellaneous effect is the effect of control voltage variation on the relay function.

File Name: 9000041128 (3578) Rev 1.doc 6/22/2011 CALCULATION NUMBER: 9000041128 REVISION:

1 PAGE 21 OF 152 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 For the purpose of this calculation the above equation will be modified for both the actuation and time delay as follows: CU = Channel Uncertainty

-The total uncertainty of an instrument channel. This is the minimum allowable difference between the design value and the nominal setpoint value. RCA = Rack Component or "String" Calibration Accuracy.

RMTE = Rack Component or "String" Measuring and Test Equipment Uncertainty.

RD = Rack Component or "String" Drift or Stability.

RTE = Rack Component or "String" Ambient Temperature Effects. RME = Rack Component or "String" Miscellaneous Effects. 5.2. Coincident Logic Considerations (Dropout)

The channel uncertainty will be calculated at 95% probability of actuation.

That means there is a 2.5% chance that the relay will actuate below "setpoint

-uncertainty" and 2.5% chance that the relay will actuate at above "setpoint

+ uncertainty".

Therefore, at the point of concern which is the lower limit, there is 97.50/0 chance that the relay will actuate above "setpoint

-uncertainty".

Calculation of the point at which there is 950/0 probability that both relays will actuate is easier for SLURs because they are both ABB 59N relays with the same mean and standard deviation of error. For SLUR dropout, when both relays have to actuate to initiate the timers, the probability of both timers to actuate above the lower limit is 97.5% X 97.5% = 95%. Therefore, the two sided random channel uncertainty calculated at 950/0 probability will correspond to 95% single sided uncertainty of a coincident logic. Therefore, for SLUR relays further scaling of uncertainty will not be required.

The setpoints of FLUR undervoltage relays for load shed; T1A, B, C & T2, have different Analytical Limit of actuation.

T2 which is an instantaneous relay must actuate before the 4KV bus voltage reaches 3411 VAC. But load shed will occur only if the bus voltage continues to degrade and further degradation is sensed by T1 A, B or C undervoltage relays. The three T1 relays are setup in a voltage tier such that T1A will actuate at the highest voltage but will have the longest time delay of the three. T1 C will have the lowest actuation voltage and will have the shortest time delay. T1 B is between the other two. This has been configured such that it maximizes equipment protection against degraded voltage yet meets the criteria of the analytical limits. Since the coincident logic for actuation of load shed has to wait till actuation of one of the T1 relays, the lower tail of uncertainty distribution of T1 setpoint will be at 97.5% confidence level. The coincident logic will be based on the actuation of T1A. Since the two sided T1A uncertainty is calculated at 95% CL (CU DO = 1.96XO'), the one sided actuation point with 95% probability will be equal to (1.645 X 0') Or in other words: (1.645/1.96)

  • CU DO 5.3. One out of two logic considerations (Pickup) File Name: 9000041128 (357S) Rev 1.doc 6/22/2011 CALCULATION NUMBER: 9000041128 REVISION:

1 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 PAGE 22 OF 152 For the pickup setpoint, the upper limit of uncertainty is of the interest.

The calculated uncertainty of one relay will provide 97.5% probability that the relay will actuate below the upper limit. The probability that no relay will actuate above the "setpoint

+ uncertainty" is 2.5% X 2.5% = 0.0625%. On the normal curve, the "Z" value corresponding to 2.5% and 0.0625% are respectively 1.96 and 2.475. The upper limit of uncertainty for one out of two logic will be calculated by multiplying the upper limit of uncertainty by a factor of (1.96/2.475).

6. Acceptance Criteria 6.1. FLUR Acceptance Criteria 6.1.1. FLUR LOW VOLTAGE SETPOINT FOR DIESEL START (27H*B2):

The 27X device in FLUR undervoltage relay detects a degraded voltage condition.

The device 27X must actuate in less than 10 seconds before the 4KV bus voltage reaches Technical Specification limit of 2583VAC. 6.1.2. FLUR LOSS OF VOLTAGE SETPOINT FOR DIESEL START (27H*B2):

The 27P device in FLUR undervoltage relay detects a loss of voltage condition.

The device 27P must actuate in less than 0.8 seconds upon loss of voltage. 6.1.3. FLUR Degraded VOLTAGE SETPOINT FOR LOAD SHED (27H*T1A, 27H*T1 B, 27H*T1 C & 27H*T2): The coincident logic must actuate in less than 10 seconds before T1 A senses a degraded voltage of 3328VAC on the 4KV bus. The coincident logic must actuate in less than 6 seconds before T1 B senses a degraded voltage of 3120VAC on the 4KV bus. The coincident logic must actuate in less than 4 seconds before T1 C senses a degraded voltage of 2704VAC on the 4KV bus. However, T2 must actuate before T1A, B or C at a voltage above the analytical limit of 3411VAC in preparation for T1 actuation.

6.2. SLUR Acceptance Criteria 6.2.1. The SLUR detects a degraded voltage condition less than or equal to 3785V on the associated 4160V Class 1 E bus to protect motors from overheating.

6.2.2. If the degraded condition persists, the SLUR will initiate a diesel start signal within 10 seconds, 6.2.3. and then it will initiate bus load shed and transfer to diesel within 20 seconds. The time delays are provided by external time delay relays, devices 62H*3A and 62H*3B. The SLUR scheme for each bus is comprised of two three phase 4160/120VAC potential transformers each supplying one SLUR. The SLUR output contacts, associated time delay relays, and various permissive contacts of other devices in the bus auto transfer scheme are supplied from the vital 125V DC System. One SLUR, device 27H*B3, is connected to the A-B phase PT and the other SLUR, device 27H*B4 is connected to the B-C phase PT. The SLUR contacts are connected in series such that both relays must dropout to initiate the diesel start and load shed time delay relays. Only one of the two SLURs is required to pick up in order to reset the diesel start and load shed time delay relays. File Name: 9000041128 (3578) Rev 1.doc 6/22/2011 CALCULATION NUMBER: 9000041128 REVISION:

1 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 SLUR Dropout PAGE 23 OF 152 The analytical limit for SLUR dropout in this calculation is the TS allowable value of 3785 volts [Ref. 12.1.2]. This limit is 91 % of the nominal 4160V bus voltage and is equal to the analytical limit based on load flow calculation 357 A-DC [Ref. 12.1.56].

The SLUR setpoint with all the uncertainties considered shall be higher than this limit. SLUR Trip Avoidance Limit DCPP Calculation 357 A-DC analyzes the availability of the offsite power source against normal operating transients.

To prevent actuation of the SLUR during normal operating transients, the trip avoidance limit of the SLUR shall be less than or equal to 3850VAC. SLUR Timers The SLUR load shed time delay should be adequate to maximize response time of LTC (Load Tap Changer) action to recover voltage. Currently the acceptance criterion for the third tap change is 16 seconds [Ref 12.1.8]. Therefore, the SLUR load shed time delay with all the uncertainties considered shall be higher than 16 seconds and lower than 20 seconds Technical Specification limit. File Name: 9000041128 (357S) Rev 1.doc 6/22/2011 CALCULATION NUMB E R: 9 0000411 28 REVISION: 1 CALC U LAT I ON T I TLE: 4.1 6 kV B us F L UR & SL U R Se tpoin t Ca l c ul a ti o n DAT E: 03/22/2 011 7. Body of Calculation 7.1. Potential Transformer Ratio Correction Factor (RCF) PAGE 24 OF 152 The potential transformer consists of two single phase transformers.

One transformer is connected to A-B phase and the other to the B-C phase. They are GE JVM-3 instrument transformer with a 35:1 turn ratio. FLOCs: DC-1/2-63-E-XF-SHF(G,H)12PT.

The exact value of the PT ratio is dependent on the PT burden. The PT burden for transformers on each bus is calculated in Attachment "1". The transformer on A-B phase is lightly loaded while on the B-C phase is heavily loaded. Using the GE "Potential Transformer Characteristic Ratio and Phase Angle Curve" (Attachment "2"), the ratio correction factor (RCF) for lightly and heavily loaded transformers on each bus is tabulated as follows: Transformer Burden Burden Power RCF PTR (VA) (W) Factor Unit 1 SHF12PT A-B 22.59 22.59 1.0 0.9986 34.951 Unit 1 SHF12PT B-C 157.72 154.76 0.98 1.0052 35.182 Unit 2 SHF12PT A-B 22.59 22.59 1.0 0.9986 34.951 Unit 2 SHF12PT B-C 157.72 154.76 0.98 1.0052 35.182 Unit 1 SHG12PT A_B 22.59 22.59 1.0 0.9986 34.951 Unit 1 SHG12PT B-C 178.65 161.69 0.91 1.0082 35.287 Unit 2 SHG12PT A_B 22.59 22.59 1.0 0.9986 34.951 Unit 2 SHG12PT B_C 178.65 161.69 0.91 1.0082 35.287 Unit 1 SHH12PT A_B 22.59 22.59 1.0 0.9986 34.951 Unit 1 SHH 12PT B-C 149.32 133.82 0.90 1.0064 35.224 Unit 2 SHH 12PT A-B 22.59 22.59 1.0 0.9986 34.951 Unit 2 SHH12PT B-C 149.32 133.82 0.90 1.0064 35.224 7.2. Bias (B) The IR losses are considered to be negligible since the loop and associated cables are located in mild environments, and the currents are not sufficiently low so as to be comparable to leakage currents generated by extreme environmental conditions. As the PT and the degraded voltage relays are located within the same switchgear room, the voltage drop between the two devices can be considered negligible.

No other source of bias term has been identified for the relay. Therefore, B=O File Name: 9000041128 (357S) Rev 1.doc 6/22/2011 CALCULATION NUMBER: 9000041128 REVISION:

1 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 7.3. Rack Calibration Accuracy (RCA) 7.3.1. RCA -27H*B2 Undervoltage Function Make and Model: Basler BE1-GPS100E4N1HO AL 27P: +/-1.48VAC [Ref. 12.1.7] AL 127P: +/-0.60VAC [Ref. 12.1.7] AL 27x: +/-0.46VAC [Ref. 12.1.7] Per input 4: VRF 27P = +/-2% X 76.3VAC = +/-1.53 VAC VRF 127P = +/-2% X 30.6VAC = +/-0.61 VAC VRF 27x = +/-2% X 23.4VAC = +/-0.47 VAC PAGE 25 OF 152 LOW Voltage" Setpoint LOW-LOW Setpoint LOSS of Voltage Setpoint Since the calibration tolerance is smaller than the vendor reference accuracy, the reference accuracy will be used as Rack Calibration Accuracy (RCAuv). Since the pickup occurs at approximately 102% of dropout [Ref. 12.1.50], the RCA value applies to both the dropout and pickup (Note: The dropout and pickup terminology used in this calculation is the opposite of that used in MP E-50.62 procedure).

=

= +/-1.53VAC

=

= +/-0.61VAC

=

= +/-0.47VAC 7.3.2. RCA -27H*B2 Time Delay Function Make and Model: Basler BE1-GPS100E4N1HO AL 27P: +/-0.30 Sec [FLOC] AL 127P: +/-0.10 Sec [FLOC] AL 27x: +/-0.05 Sec [FLOC] Per input 4.2: VRF 27P = +/-5% X 4.7 Sec = +/-0.235000 Sec VRF 127P = +/-5% X 1.9 Sec = +/-0.095000 Sec VRF 27x = larger of +/-5% X 0.65 Sec and +/-0.05 Sec LOW Voltage" Setpoint LOW-LOW Setpoint LOSS of Voltage Setpoint Since the calibration tolerance is larger than the vendor reference accuracy, the AL tolerance will be used as Rack Calibration Accuracy (RCA TD) RCATD_27P:

+/-0.30 Sec RCATD_127P:

+/-O.1 0 Sec RCATD_27X:

+/-0.05 Sec 7.3.3. RCA -27H*T1A Undervoltage Function:

File Name: 9000041128 (357S) Rev 1.doc 6/22/2011 CALCULATION NUMBER: 9000041128 REVISION:

1 PAGE 26 OF 152 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 Make and Model: ABB 27N Dropout LOW VOLTAGE SETPOINT At 96.5VAC setting, the vendor reference accuracy per input 4.3 is: VRFoo = +/-0.1% X 96.5 VAC = +/-0.1 VAC M& TE used to calibrate this relay cannot achieve the vendor reference accuracy.

Hence the recommended ALoo tolerance is +/-0.5VAC. [See Section 7.4.3] Per CF6.NE1 [ref. 12.1.1] Rack Calibration Accuracy (RCA uv) is the larger of VRFoo and ALoo . Hence: RCAuv_oo = +/-0.5VAC. 7.3.4. RCA -27H*T1 B Undervoltage Function:

Make and Model: ABB 27N Dropout LOW LOW VOLTAGE SETPOINT At 90.5VAC setting, the vendor reference accuracy per input 4.3 is: VRFoo = +/-0.1 % X 90.5 VAC = +/-0.09 VAC M& TE used to calibrate this relay cannot achieve the vendor reference accuracy.

Hence the recommended ALoo tolerance is +/-0.5VAC. [See Section 7.4.4] Per CF6.NE1 [ref. 12.1.1] Rack Calibration Accuracy (RCA uv) is the larger of VRFoo and ALoo . Hence: RCAuv_oo = +/-0.5VAC. 7.3.5. RCA -27H*T1 C Undervoltage Function:

Make and Model: ABB 27N Dropout LOSS OF VOLTAGE SETPOINT At 78.6VAC setting, the vendor reference accuracy per input 4.3 is: VRFoo = +/-0.1% X 78.6 VAC = +/-0.08 VAC M& TE used to calibrate this relay cannot achieve the vendor reference accuracy.

Hence the recommended ALoo tolerance is +/-0.5VAC. [See Section 7.4.5] Per CF6.NE1 [ref. 12.1.1] Rack Calibration Accuracy (RCA uv) is the larger of VRFoo and ALoo . Hence: RCAuv_oo = +/-0.5VAC. 7.3.6. RCA -27H*T1A Time Delay Function (LOW VOLTAGE):

Make and Model: ABB Type 27N At 8 sec setting, the vendor reference accuracy per input 4.4 is: Reference Accuracy for time delay function is +/-100/0 of setting or +/-20 ms whichever is greater. File Name: 9000041128 (3578) Rev 1.doc 6/22/2011 CALCULATION NUMBER: 9000041128 REVISION:

1 PAGE 27 OF 152 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 VRF TO = +/-100/0 x 8 sec = +/-0.8 sec. This value is larger than 20ms. To allow for margin, recommended ALTo tolerance is +/-1.0sec. Per CF6.NE1 [ref. 12.1.1] Rack Calibration Accuracy (RCA uv) is the larger of VRF TO and ALTo . Hence: RCAuv_To = +/-1.0 sec. 7.3.7. RCA -27H*T1 S Time Delay Function (LOW-LOW VOLTAGE):

Make and Model: ASS Type 27N At 5 sec setting, the vendor reference accuracy per input 4.4 is: Reference Accuracy for time delay function is +/-10% of setting or +/-20 ms whichever is greater. VRF TO = +/-10% x 5 sec = +/-0.5 sec. This value is larger than 20ms. To allow for margin, recommended ALTo tolerance is +/-0.7sec. Per CF6.NE1 [ref. 12.1.1] Rack Calibration Accuracy (RCA uv) is the larger of VRF TO and ALTo . Hence: RCAuv_To = +/-0.7 sec. 7.3.8. RCA -27H*T1C Time Delay Function (LOSS OF VOLTAGE):

Make and Model: ASS Type 27N At 3 sec setting, the vendor reference accuracy per input 4.4 is: Reference Accuracy for time delay function is +/-10% of setting or +/-20 ms whichever is greater. VRF TO = +/-10% x 3 sec = +/-0.3 sec. This value is larger than 20ms. To allow for margin, recommended ALTo tolerance is +/-0.5sec. Per CF6.NE1 [ref. 12.1.1] Rack Calibration Accuracy (RCAuv) is the larger of VRF TO and ALTo. Hence: RCAuv_To = +/-0.5 sec. 7.3.9. RCA -27H*T2 Undervoltage Function Make and Model: ASS Type 59N Dropout At 98.0VAC setting, the vendor reference accuracy per input 4.3 is: VRFoo = +/-0.1 % X 98.0 VAC = +/-0.098 VAC M& TE used to calibrate this relay cannot achieve the vendor reference accuracy.

Hence the recommended ALoo tolerance is +/-0.5VAC. [See Section 7.4.9] File Name: 9000041128 (3578) Rev 1.doc 6/22/2011 CALCULATION NUMBER: 9000041128 REVISION:

1 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 PAGE 28 OF 152 Per CF6.NE1 [ref. 12.1.1] Rack Calibration Accuracy (RCA uv) is the larger of VRFoo and ALoo . Hence: RCAuv_oo = +/-0.5VAC. 7.3.10. RCA -27H*T2 Time Delay Function (Pickup = Reset) Make and Model: ABB Type 59N Due to the use of the harmonic filter on the T2 relays, an instantaneous model cannot be used. Hence a definite time delay relay will be used with the time delay dialed to the minimum setpoint of 0.1 second. This time delay occurs on the pickup action of the relay. Reference Accuracy for time delay function is +/-10% of setting or +/-20 ms whichever is greater [Ref.12.1.51].

The uncertainty at the lowest time delay setting per vendor reference accuracy is 20 milliseconds.

This means that the pick up can occur anywhere between 80 to 120 milliseconds.

Therefore, RCA To = +/-0.02 sec. 7.3.11. RCA -27H*B3 Undervoltage Function Make and Model: ABB Type 59N Dropout At 109.25VAC setting, the vendor reference accuracy per input 4.3 is: VRFoo = +/-0.1% X 109.25 VAC = +/-0.11 VAC M& TE used to calibrate this relay cannot achieve the vendor reference accuracy.

Hence the recommended ALoo tolerance is +/-0.5VAC. [See Section 7.4.11] Per CF6.NE1 [ref. 12.1.1] Rack Calibration Accuracy (RCA uv) is the larger of VRFoo and ALoo . Hence: RCAuv_oo = +/-0.5VAC 7.3.12. RCA -27H*B3 Time Delay Function Make and Model: ABB Type 59N Due to the use of the harmonic filter on the B2 relays, an instantaneous model cannot be used. Hence a definite time delay relay will be used with the time delay dialed to the minimum setpoint of 0.1 second. This time delay occurs on the pickup action of the relay. Reference Accuracy for time delay function is +/-100/0 of setting or +/-20 ms whichever is greater [Ref. 12.1.51].

The uncertainty at the lowest time delay setting per vendor reference accuracy is 20 milliseconds.

This means that the pick up can occur anywhere between 80 to 120 milliseconds.

Therefore, RCA To = +/-0.02 sec. File Name: 9000041128 (357S) Rev 1.doc 6/22/2011 CALCULATION NUMBER: 9000041128 REVISION:

1 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 7.3.13. RCA -27H*B4 Undervoltage Function Make and Model: ABB Type 59N Dropout PAGE 29 OF 152 At 109.25VAC setting, the vendor reference accuracy per input 4.3 is: VRFoo = +/-0.10/0 X 109.25 VAC = +/-0.11 VAC M& TE used to calibrate this relay cannot achieve the vendor reference accuracy.

Hence the recommended ALoo tolerance is +/-0.5VAC. [See Section 7.4.13] Per CF6.NE1 [ref. 12.1.1] Rack Calibration Accuracy (RCA uv) is the larger of VRFoo and ALoo . Hence: RCAuv_oo = +/-0.5VAC. 7.3.14. RCA -27H*B4 Time Delay Function Make and Model: ABB Type 59N Due to the use of the harmonic filter on the B4 relays, an instantaneous model cannot be used. Hence a definite time delay relay will be used with the time delay dialed to the minimum setpoint of 0.1 second. This time delay occurs on the pickup action of the relay. Reference Accuracy for time delay function is +/-100/0 of setting or +/-20 ms whichever is greater [Ref. 12.1.51].

The uncertainty at the lowest time delay setting per vendor reference accuracy is 20 milliseconds.

This means that the pick up can occur anywhere between 80 to 120 milliseconds.

Therefore, RCA To = +/-0.02 sec. 7.3.15. RCA -62H*3A Time Delay Function Make and Model: ABB 62T Per input 4.5, ABB 62T timer reference accuracy at 8.5 seconds time delay is +/-0.5% or +/-15ms or +/- 1 digit of setting (whichever is greater).

VRF To = +/-0.5% x 8.5 sec = +/-0.0425 sec. This is larger than 15ms or 1 digit which is 10 ms. The M& TE is capable of calibration to a tolerance of 0.6 milliseconds

[See Section 7.4.15]. Therefore for the purpose of conservatism a calibration tolerance of 50 milliseconds will be assumed. Per CF6.NE1 [ref. 12.1.1] Rack Calibration Accuracy (RCA To) is the larger of VRF To and ALTo. Hence: RCA To = +/-0.05 sec. 7.3.16. RCA -62H*3B Time Delay Function Make and Model: ABB 62T File Name: 9000041128 (357S) Rev 1.doc 6/22/2011 CALCULATION NUMBER: 9000041128 REVISION:

1 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 PAGE 30 OF 152 Per input 4.5, ASS 62T timer reference accuracy at 18.5 seconds time delay is +/-0.5% or +/-15ms or +/- 1 digit of setting (whichever is greater).

VRF TO = +/-0.5% x 18.5 sec = +/-0.0925 sec. One digit of the setting corresponds to 100 ms. Since this is larger than the calculated VRF TO and larger than 15ms, VRF TO will be +/- 0.1 sec. The M& TE is capable of calibration to a tolerance of 10 milliseconds

[See Section 7.4.16]. Therefore for the purpose of conservatism a calibration tolerance of 100 milliseconds will be assumed. Per CF6.NE1 [ref. 12.1.1] Rack Calibration Accuracy (RCA To) is the larger of VRF TO and ALTo. Hence: RCA To = +/-O.1 sec. File Name: 9000041128 (357S) Rev 1.doc 6/22/2011 CALCULATION NUMBER: 9000041128 REVISION:

1 PAGE 31 OF 152 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 7.4. Rack Measurement

& Test Equipment Effect (RMTE) The Rack Measurement

& Test Equipment Effect (RMTE) is the "As-Left Tolerance AL". 7.4.1. RMTE -27H*B2 Undervoltage Function STP 27P: 76.3 VAC [FLOC] STP 127P: 30.6 VAC [FLOC] STP 27X: 23.4 VAC [FLOC] LOW Voltage" Setpoint LOW-LOW Setpoint LOSS of Voltage Setpoint Per input 4.6, the M& TE tolerance is computed at each setpoint as follows: RMTE 27P = +/-(0.06% X 76.3 + 0.03% X 750)VAC = +/-0.271 VAC RMTE 127P = +/-(0.06% X 30.6 + 0.03% X 750)VAC = +/-0.243 VAC RMTE 27X = +/-(0.06% X 23.4 + 0.03% X 750)VAC = +/-0.239 VAC 7.4.2. RMTE -27H*B2 Time Delay Function STP 27P: 4.7 Sec [FLOC] STP 127P: 1.9 Sec [FLOC] STP 27X: 0.65 Sec [FLOC] LOW Voltage Setpoint LOW-LOW Setpoint LOSS of Voltage Setpoint Per input 4.7, the M&TE tolerance is computed at each setpoint as follows: RMTE 27P = +/-(0.005% X 4.7 + 0.0001) Sec = +/-0.000335 Sec RMTE 127P = +/-(0.005% X 1.9 + 0.0001) Sec = +/-0.000195 Sec RMTE 27X = +/-(0.005% X 0.65 + 0.0001) Sec = +/-0.000133 Sec 7.4.3. RMTE -27H*T1A Undervoltage Function:

STP oo: 96.5 VAC LOW Voltage Setpoint Per input 4.8, the M& TE tolerance at the measured setpoint is as follows: RMTE = +/-(0.06% X 96.5 + 0.03% X 750) VAC = +/-0.28VAC 7.4.4. RMTE -27H*T1 B Undervoltage Function:

STP oo: 90.5 VAC LOW-LOW Voltage Setpoint Per input 4.8, the M& TE tolerance at the measured setpoint is as follows: RMTE = +/-(0.06% X 90.5 + 0.03% X 750) VAC = +/-0.28VAC 7.4.5. RMTE -27H*T1 C Undervoltage Function:

STP oo: 78.6 VAC LOSS of Voltage Setpoint Per input 4.8, the M& TE tolerance at the measured setpoint is as follows: RMTE = +/-(0.06% X 78.6 + 0.03% X 750) VAC = +/-0.27VAC 7.4.6. RMTE -27H*T1A Time Delay Function:

STP TO: 8.0 sec LOW Voltage Setpoint File Name: 9000041128 (357S) Rev 1.doc 6/22/2011 CALCULATION NUMBER: 9000041128 REVISION:

1 PAGE 32 OF 152 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 Per input 4.7, the M&TE tolerance at the measured setpoint is as follows: RMTE = +/-(0.010/0 X 8.0 + 0.01) sec = +/-0.01sec 7.4.7. RMTE -27H*T1 B Time Delay Function:

STP TO: 5.0 sec LOW-LOW Voltage Setpoint Per input 4.7, the M& TE tolerance at the measured setpoint is as follows: RMTE = +/-(0.010/0 X 5.0 + 0.01) sec = +/-0.01sec 7.4.8. RMTE -27H*T1 C Time Delay Function:

STP TO: 3.0 sec LOSS of Voltage Setpoint Per input 4.7, the M&TE tolerance at the measured setpoint is as follows: RMTE = +/-(0.01 % X 3.0 + 0.01) sec = +/-0.01 sec 7.4.9. RMTE -27H*T2 Undervoltage Function:

STP oo: 98.0 VAC Per input 4.8, the M& TE tolerance at the measured setpoint is as follows: RMTE = +/-(0.06% X 98.0 + 0.03%) X 750) VAC = +/-0.28VAC 7.4.10. RMTE -27H*T2 Time Delay Function:

STP TO: 0.1 sec (Time Delay on Pickup) Per input 4.7, the M& TE tolerance at the measured setpoint is as follows: RMTE = +/-(0.01 % X 0.1 + 0.01) sec = +/-0.01 sec 7.4.11. RMTE -27H*B3 Undervoltage Function STP oo: 109.25 VAC [FLOC] Per input 4.8, the M& TE tolerance at the measured setpoint is as follows: RMTE = +/-(0.06% X 109.25 + 0.03% X 750) VAC = +/-0.29VAC 7.4.12. RMTE -27H*B3 Time Delay Function STP TO = 0.1 Sec Per input 4.7, the M&TE tolerance at the measured setpoint is as follows: RMTE = +/-(0.01 % X 0.1 + 0.01) Sec = 0.01 Sec 7.4.13. RMTE -27H*B4 Undervoltage Function STP oo: 109.25 VAC [FLOC] Per input 4.8, the M& TE tolerance at the measured setpoint is as follows: RMTE = +/-(0.06% X 109.25 + 0.03% X 750) VAC = +/-0.29VAC 7.4.14. RMTE -27H*B4 Time Delay Function STP TO = 0.1 Sec File Name: 9000041128 (357S) Rev 1.doc 6/22/2011 CALCULATION NUMBER: 9000041128 REVISION:

1 PAGE 33 OF 152 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 Per input 4.7, the M&TE tolerance at the measured setpoint is as follows: RMTE = +/-(0.01 % X 0.1 + 0.01) Sec = 0.01 Sec 7.4.15. RMTE -62H*3A Time Delay Function STP TD = 8.5 Sec Per input 4.9, the M& TE tolerance at the measured setpoint is as follows: RMTE = +/-(0.01 % X 8.5 + 0.01) Sec = 0.01 Sec 7.4.16. RMTE -62H*38 Time Delay Function STP TD = 18.5 Sec Per input 4.9, the M&TE tolerance at the measured setpoint is as follows: RMTE = +/-(0.010/0 X 18.5 + 0.01) Sec = 0.01 Sec File Name: 9000041128 (357S) Rev 1.doc 6/22/2011 CALCULATION NUMBER: 9000041128 REVISION:

1 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 7.5. Rack Drift (RD) [as calculated in Attachment 3] 7.5.1. RD -27H*82 Undervoltage Function DR 27P Dropout: +/-O.SO VAC DR 127P Dropout: +/-0.30 VAC DR 27X Dropout: +/-OAO VAC 7.5.2. RD -27H*82 Time Delay Function DR 27P Dropout: +/-O.1 sec DR 127P Dropout: +/-O.OS sec DR 27X Dropout: +/-O.OS sec 7.5.3. RD -27H*T1A Undervoltage Dropout Function:

RD DO = +/-0.34VAC 7.SA. RD -27H*T1A Time Delay Function:

RDTD = +/-O .18sec 7.5.5. RD -27H*T1 8 Undervoltage Function RD DO = +/-0.31VAC 7.5.6. RD -27H*T1 8 Time Delay Function:

RDTD = +/-0.18sec 7.5.7. RD -27H*T1 C Undervoltage Function RD DO = +/-0.27VAC 7.5.8. RD -27H*T1 C Time Delay Function:

RDTD = +/-0.18sec 7.5.9. RD -27H*T2 Undervoltage Function RD DO = +/-0.34VAC 7.5.10. RD -27H*T2 Time Delay Function (on Pickup) RDTD = +/-0.02sec 7.5.11. RD -27H*83 Undervoltage Function RD DO = +/-0.37VAC 7.5.12. RD -27H*83 Time Delay Function (on Pickup) RDTD = +/-0.02sec 7.5.13. RD -27H*84 Undervoltage Function File Name: 9000041128 (357S) Rev 1.doc PAGE 34 OF 152 6/22/2011 CALCULATION NUMBER: 9000041128 REVISION:

1 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 RD = +/-O.37VAC 7.5.14. RD -27H*84 Time Delay Function (on Pickup) RDTD = +/-O.02 Sec 7.5.15. RD -62H*3A Time Delay Function RD = +/-O.17 Sec 7.5.16. RD -62H*38 Time Delay Function RD = +/-O.37 Sec File Name: 9000041128 (357S) Rev 1.doc PAGE 35 OF 152 6/22/2011 CALCULATION NUMBER: 9000041128 REVISION:

1 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 7.6. Rack Temperature Effect (RTE) 7.6.1. RTE -27H*B2 Undervoltage Function Make and Model: Basler BE1-GPS100E4N1 HO RTE = 0 [Assumption 3.2] 7.6.2. RTE -27H*B2 Time Delay Function Make and Model: Basler BE1-GPS100E4N1HO RTE = 0 [Assumption 3.2] 7.6.3. RTE -27H*T1A Undervoltage Function:

Make and Model: ABB 27N RTE = 0.33% x Setpoint [Assumption 4.10] RTE = 0.33% x 96.5 VAG RTE = 0.32 VAG 7.6.4. RTE -27H*T1 B Undervoltage Function:

Make and Model: ABB 27N RTE = 0.33% x Setpoint [Assumption 4.10] RTE = 0.33% x 90.5 VAG RTE = 0.3 VAG 7.6.5. RTE -27H*T1 G Undervoltage Function:

Make and Model: ABB 27N RTE = 0.33% x Setpoint [Assumption 4.10] RTE = 0.330/0 x 78.6 VAG RTE = 0.26 VAG 7.6.6. RTE -27H*T1A Time Delay Function:

Make and Model: ABB 27N RTE = 0 [Assumption 4.10] 7.6.7. RTE -27H*T1B Time Delay Function:

Make and Model: ABB 27N RTE = 0 [Assumption 4.10] 7.6.8. RTE -27H*T1 G Time Delay Function:

Make and Model: ABB 27N RTE = 0 [Assumption 4.10] File Name: 9000041128 (357S) Rev 1.doc PAGE 36 OF 152 6/22/2011 CALCULATION NUMBER: 9000041128 REVISION:

1 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 7.6.9. RTE -27H*T2 Undervoltage Function:

Make and Model: ABB 59N RTE = 0.33% x Setpoint [Assumption 4.10] RTE = 0.33% x 98.0 VAG RTE = 0.32 VAG 7.6.10. RTE -27H*T2 Time Delay Function (on Pickup): Make and Model: ABB 59N RTE = 0 [Assumption 4.10] 7.6.11. RTE -27H*S3 Undervoltage Function:

Make and Model: ABB 59N RTE = 0.33% x Setpoint [Assumption 4.10] RTE = 0.33% x 109.25 VAG RTE = 0.36 VAG 7.6.12. RTE -27H*B3 Time Delay Function (on Pickup): Make and Model: ASB 59N RTE = 0 [Assumption 4.10] 7.6.13. RTE -27H*B4 Undervoltage Function:

Make and Model: ABB 59N RTE = 0.33% x Setpoint [Assumption 4.10] RTE = 0.33% x 109.25 VAG RTE = 0.36 VAG 7.6.14. RTE -27H*B4 Time Delay Function (on Pickup): Make and Model: ASB 59N RTE = 0 [Assumption 4.10] 7.6.15. RTE -62H*3A Time Delay Function Make and Model: ABB 62T RTE = 0.05 Sec [see 4.11] 7.6.16. RTE -62H*3B Time Delay Function Make and Model: ABS 62T RTE=0.11 Sec [see4.11]

File Name: 9000041128 (357S) Rev 1.doc PAGE 37 OF 152 6/22/2011 CALCULATION NUMBER: 9000041128 REVISION:

1 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 7.7. Rack Miscellaneous Effects (RME) 7.7.1. RME -27H*T1A Undervoltage Function:

Make and Model: ABB 27N RME = 0.1% x Setpoint [see 4.13] RME = 0.1 % x 96.5 VAG RME = 0.1 VAG 7.7.2. RME -27H*T1 B Undervoltage Function:

Make and Model: ABB 27N RME = 0.1 % x Setpoint [see 4.13] RME = 0.10/0 x 90.5 VAG RME = 0.09 VAG 7.7.3. RME -27H*T1G Undervoltage Function:

Make and Model: ABB 27N RME = 0.1% x Setpoint [see 4.13] RME = 0.10/0 x 78.6 VAG RME = 0.08 VAG 7.7.4. RME -27H*T1A Time Delay Function:

Make and Model: ABB 27N RME = 0 [see 4.13] 7.7.5. RME -27H*T1 B Time Delay Function:

Make and Model: ABB 27N RME = 0 [see 4.13] 7.7.6. RME -27H*T1G Time Delay Function:

Make and Model: ABB 27N RME = 0 [see 4.13] 7.7.7. RME -27H*T2 Undervoltage Function:

Make and Model: ABB 59N RME = 0.1% x Setpoint [see 4.13] RME = 0.1% x 98 VAG RME = 0.1 VAG 7.7.8. RME -27H*T2 Time Delay Function (on Pickup): Make and Model: ABB 59N File Name: 9000041128 (357S) Rev 1.doc PAGE 38 OF 152 6/22/2011 CALCULATION NUMBER: 9000041128 REVISION:

1 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 RME = 0 [see 4.13] 7.7.9. RME -27H*B3 Undervoltage Function:

Make and Model: ASS 59N RME = 0.1 % x Setpoint [see 4.124.13]

RME = 0.10/0 x 109.25 VAG RME = 0.11 VAG 7.7.10. RME -27H*B3 Time Delay Function (on Pickup): Make and Model: ASS 59N RME = 0 [see 4.124.13]

7.7.11. RME -27H*S4 Undervoltage Function:

Make and Model: ASS 59N RME = 0.1 % x Setpoint [see 4.124.13]

RME = 0.1% x 109.25 VAG RME = 0.11 VAG 7.7.12. RME -27H*S4 Time Delay Function (on Pickup): Make and Model: ABS 59N RME = 0 [see 4.13] 7.7.13. RME -62H*3A Time Delay Function Make and Model: ABS 62T RME = 0.17 sec [see 4.14] 7.7.14. RME -62H*3B Time Delay Function Make and Model: ASS 62T RME = 0.37 sec [see 4.14] File Name: 9000041128 (3578) Rev 1.doc PAGE 39 OF 152 6/22/2011 CALCULATION NUMBER: 9000041128 REVISION:

1 PAGE 40 OF 152 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 7.8. Device Level Uncertainty 7.8.1. 27H*B2 Undervoltage Actuation Uncertainty

-CU 27H*B2 Undervoltage Setpoints

[Ref. 12.1.7]: 27P: 76.3 VAG 127P: 30.6 VAG 27X: 23.4 VAG CU 27H*B2= B+/- RCA2+RMTE2+RD2+

RTE2 )

= O+/-

)= +/-1.632VAC

= 0 +/-

0.30 2+0 2 )= +/-0.722 VAC

= O+/-

)= +/-0.662VAC 7.8.2. 27H*B2 Time Delay Uncertainty

-

Undervoltage Setpoints

[Ref. 12.1.7]: 27P: 4.7 Sec 127P: 1.9 Sec 27X: 0.65 Sec CU 27H*B2= B+/- RCA2+RMTE2+RD2+

RTE2 ) CUJfH*B2_27P

= O+/-

)= +/-0.316sec CUJfH*B2_127P

= 0 +/-

)= +/-0.112sec CUJfH*B2_27X

= 0 +/- 0.050 2+0.000133 2+0.05 2+0 2 )= +/-0.071sec 7.8.3. 27H*T1A Actuation Uncertainty

-CU 27H*TlA CU 27H*TlA = B +/- (.J RCA 2 + RMTE2 + RD2 + RTE2 + RME2 ) CU 2;H*TlA = 0+/-(.JO.5 2 +0.28 2 +0.34 2 +0.322 +0.1 2 )=+/-0.75VAC 7.8.4. 27H*T1 B Actuation Uncertainty

-CU 27 H*TlB CU 27H*TlB = B +/- (.J RCA 2 + RMTE2 + RD2 + RTE2 + RME2 ) CU 27H*TlB =0+/-(.JO.5 2 +0.28 2 +0.312 +0.30 2 +0.09 2 )=+/-0.72VAC File Name: 9000041128 (357S) Rev 1.doc 6/22/2011 CALCULATION NUMBER: 9000041128 REVISION:

1 PAGE 41 OF 152 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 7.8.5. 27H*T1C Actuation Uncertainty

-CU 27H*TlC CU 27H*TlC = B +/- (J RCA 2 + RMTE2 + RD2 + RTE2 + RME2 ) CU 27H*TlC = 0 +/- (.JO.5 2 + 0.27 2 + 0.272 + 0.26 2 + 0.08 2 )= +/-0.69 VAC 7.8.6. 27H*T1A Time Delay Uncertainty

-

= B +/- (J RCA 2 + RMTE2 + RD2 + RTE2 + RME2 )

= 0 +/- (J1.0 2 + 0.012 + 0.18 2 + 0 2 + 0 2 )= +/-1.02sec 7.8.7. 27H*T18 Time Delay Uncertainty

-

= B +/- (J RCA 2 + RMTE2 + RD2 + RTE2 + RME2 )

= O+/- (.JO.7 2 + 0.012 + 0.18 2 + 0 2 + 0 2 )= +/-0.72 sec 7.8.8. 27H*T1C Time Delay Uncertainty

-

= B +/- (J RCA 2 + RMTE2 + RD2 + RTE2 + RME2 )

= 0 +/- (.JO.5 2 + 0.012 + 0.18 2 + 0 2 + 0 2 )= +/-0.53 sec 7.8.9. 27H*T2 Actuation Uncertainty

-CU 27H*T2 CU 27H*T2 = B +/- (J RCA 2 + RMTE2 + RD2 + RTE2 + RME2 ) CU 27H*T2 = O+/- (JO.5 2 + 0.28 2 + 0.342 + 0.322 + 0.12 )= +/-0.75 VAC 7.8.10. 27H*T2 Time Delay Uncertainty (on Pickup) -

= B +/- (J RCA 2 + RMTE2 + RD2 + RTE2 + RME2 )

= 0 +/- (.JO.02 2 + 0.012 + 0.022 + 0 2 + 0 2 )= +/-0.03 sec 7.8.11. 27H*83 Undervoltage Actuation Uncertainty

-CU 27H*B3 CU 27H*B3 = B +/- (J RCA 2 + RMTE2 + RD2 + RTE2 + RME2 ) CU 27H*B3 = 0 +/- (.JO.5 2 + 0.29 2 + 0.37 2 + 0.36 2 + 0.112 )= +/-0.78 VAC File Name: 9000041128 (357S) Rev 1.doc 6/22/2011 CALCULATION NUMBER: 9000041128 REVISION:

1 PAGE 42 OF 152 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 7.8.12. 27H*83 Time Delay Actuation Uncertainty (on Pickup) -

= RCA 2 + RMTE2 + RD2 + RTE2 + RME2

= 0 +/- (JO.02 2 + 0.012 + 0.022 + 0 2 + 0 2 )= +/-0.03 sec 7.8.13. 27H*84 Actuation Uncertainty

-CU 27H*B4 CU 27H*B4 = B +/- (J RCA 2 + RMTE2 + RD2 + RTE2 + RME2 ) CU 27H*B4 = 0 +/- (JO.5 2 + 0.29 2 + 0.37 2 + 0.36 2 + 0.11 2 )= +/-0.78 VAC 7.8.14. 27H*84 Time Delay Uncertainty (on Pickup) -

= B +/- (J RCA 2 + RMTE2 + RD2 + RTE2 + RME2 )

= 0 +/- (JO.02 2 + 0.012 + 0.022 + 0 2 + 0 2 )= +/-0.03 sec 7.8.15. 62H*3A Time Delay Uncertainty

-

= B +/- (J RCA 2 + RMTE2 + RD2 + RTE2 + RME2 )

= 0 +/- (.JO.05 2 + 0.012 + 0.17 2 + 0.05 2 + 0.172 )= +/-0.25 sec 7.8.16. 62H*38 Time Delay Uncertainty

-

= B +/- (J RCA 2 + RMTE2 + RD2 + RTE2 + RME2 )

= 0 +/- (.J0.1 2 + 0.012 + 037 2 + 0.11 2 + 0.37 2 )= +/-0.54 sec File Name: 9000041128 (357S) Rev 1.doc 6/22/2011 CALCULATION NUMBER: 9000041128 REVISION:

1 PAGE 43 OF 152 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 7.9. FLUR 2/2 Logic Undervoltage Load Shed Dropout Uncertainty (CUFLUR_DO)

Per section 5.2, CUFLUR_DO

= +/-(1.645/1.96)

X Since the T1 relays have lower setpoints than the T2, the 2/2 logic actuation is determined by the lowest bus voltage sensed by T1 A at 3373V. This can be tested as follows: The T1A 950/0 single sided voltage uncertainty is 0.75V X (1.645/1.96)

= 0.63V T1A Trip Avoidance Limit = 96.5V + 0.63V = 97.13V T1A Trip Avoidance limit = 97.13V

  • 34.951 = 3395V (81.610/0)

The lowest T1A sensed voltage = 96.5 -0.63 = 95.87V The lowest bus voltage = 95.87V

  • 34.951 = 3351V The T1A 95% single sided time delay uncertainty is 1.02s X (1.645/1.96)

= 0.86 Maximum time delay = 8.0 s + 0.86 = 8.86s. The T1 B 950/0 single sided voltage uncertainty is 0.72V X (1.645/1.96)

= 0.60V T1 B Trip Avoidance Limit = 90.50V + 0.60V = 91.1 OV T1 B Trip Avoidance limit = 91.1 OV

  • 34.951 = 3184V (76.54%) The lowest T1 B sensed voltage = 90.5 -0.60 = 89.90V The lowest bus voltage = 89.90V
  • 34.951 = 3142V The T1 B 95% single sided time delay uncertainty is 0.72s X (1.645/1.96)

= 0.60 Maximum time delay = 5.0 s + 0.60 = 5.60s. The T1 C 950/0 single sided voltage uncertainty is 0.69V X (1.645/1.96)

= 0.58V T1 C Trip Avoidance Limit = 78.60V + 0.58V = 79.18V T1 C Trip Avoidance limit = 79.18V

  • 34.951 = 2767V (66.52%) The lowest T1 C sensed voltage = 78.6 -0.58 = 78.02V The lowest bus voltage = 78.02V
  • 34.951 = 2727V The T1 C 95% single sided time delay uncertainty is 0.53s X (1.645/1.96)

= 0.44 Maximum time delay = 3.0 s + 0.44 = 3.44s. 7.10. SLUR 2/2 Logic Dropout Uncertainty (CUSLUR_DO)

Per section 5.2, CUSLUR_DO

=

=

File Name: 9000041128 (357S) Rev 1.doc 6/22/2011 CALCULATION NUMBER: 9000041128 REVISION:

1 PAGE 44 OF 152 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 CUSLUR_DO=

+/-O.78 VAC 83 lowest trip voltage = (109.25 -0.78)V X 34.951 = 3791V 84 lowest trip voltage = (109.25 -0.78)V X 35.182 = 3816V Since during bus voltage degradation 83 actuates after 84 the 2/2 logic for SLUR actuation is 3791V or 91.13% bus voltage File Name: 9000041128 (357S) Rev 1.doc 6/22/2011 CALCULATION NUMBER: 9000041128 REVISION:

1 PAGE 45 OF 152 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 7.11. Analytical Limits (AL) 7.11.1. 7.11.2. 7.11.3. 7.11.4. 7.11.5. 7.11.6. 7.11.7. 27H*T1A (Time Delayed) Low Voltage The analytical limit for the time delayed initiation of load shed is established at 3328VAC (-80% bus voltage) within 10 seconds. There is no analytical limit for relay pickup. The 80% limit at 10 seconds is selected to ensure the motors will start and if they are running their protection relays will not trip prior to shedding the bus. This ensures availability of the motors during an accident.

27H*T18 (Time Delayed) Low-Low Voltage The analytical limit for the time delayed initiation of load shed is established at 3120VAC (-750/0 bus voltage) within 6 seconds. There is no analytical limit for relay pickup. The 750/0 limit at 6 seconds is selected to maximize the time needed for voltage recovery without tripping the motor over load protection prior to shedding the bus. This ensures availability of the motors during an accident.

27H*T1 C (Time Delayed) Loss of Voltage The analytical limit for the time delayed initiation of load shed is established at 2704VAC (-65% bus voltage) within 4 seconds. There is no analytical limit for relay pickup. The 65% limit is selected to allow for clearing of a temporary fault and successful bus transfer to offsite power during a loss of voltage event. This prevents spurious transfers to diesel generators during availability of offsite power. 27H*T2 (Instantaneous)

The analytical limit for the instantaneous initiation of load shed is established at 3411VAC (-82 0/0 bus voltage).

There is no analytical limit for relay pickup. 27H*82 (Time Delayed) The 27H*82 relay has two diesel start analytical limits for "LOW voltage", and "LOSS of Voltage" and one diesel start nominal setpoint at "LOW-LOW Voltage".

The "LOW' diesel start analytical limit is 2583VAC (-62% bus voltage) within 10 seconds [Ref. 12.1.2]. The "LOSS of Voltage" diesel start analytical limit is OVAC within 0.8 seconds. The "LOW-LOW Voltage" nominal setpoint is established at bus voltage of 1070VAC (-26% bus voltage) within 1.9 seconds. There is no analytical limit for relay pickup. 27H*83 & 84 (Initiate Timer) The analytical limit for second level voltage protection is established at 3785VAC (-91 % bus voltage) [Ref. 12.1.3]. The pickup should occur at a voltage below the worst case 4KV bus voltage CWP pump starts. This level is established at 3866 VAC in Ref. 12.1.56. 62H*3A (Timer) The analytical limit for time delayed diesel start is established at 10 seconds [Ref. 12.1.3]. File Name: 9000041128 (357S) Rev 1.doc 6/22/2011 CALCULATION NUMBER: 9000041128 REVISION:

1 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 7.11.8. 62H*38 (Timer) PAGE 46 OF 152 The analytical limit for time delayed initiation of load shed is established at 20 seconds [Ref. 12.1.3]. File Name: 9000041128 (3578) Rev 1.doc 6/22/2011 CALCULATION NUMBER: 9000041128 REVISION:

1 PAGE 47 OF 152 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 7.12. Determination of Setpoint Limits and Acceptable As-Found Settings 7.12.1. 27H*B2 Undervoltage Setpoint Limit (Low Voltage) 76.3VAC [Ref. 12.1.7] PT Ratio: 34.951 [Attachment 1]

Bus Equivalent Setpoint:

76.3 X 34.951 = 2667VAC Tech Spec Limit @ 4KV Bus: 2583 VAC Tech Spec Limit @ Relay = (2583/34.951)

VAC = 73.90 VAC

-

= (76.3 -1.63)VAC

= 74.67VAC

+

= (76.3 + 1.63)VAC = 77.93VAC Min. Bus Equivalent STP: 74.67VAC X 34.951 = 2610VAC Max. Bus Equivalent STP: 77.93VAC X 34.951 = 2724VAC Margin to TS Limit = (2610 -2583)VAC = 27VAC Margin to TS Limit @ Relay = 27VAC/34.951

= 0.77VAC Limit: (76.30 -O. 77)VAC 75.53 AC 7.12.2. 27H*B2 Undervoltage Setpoint Limit (Low-Low Voltage) 30.6VAC

-

= (30.6 -0.722)VAC

= 29.878VAC

+

= (30.6 + 0.722)VAC

= 31.322VAC Min. Bus Equivalent STP: 29.878VAC X 34.951 = 1044VAC Max. Bus Equivalent STP: 31.322VAC X 34.951 = 1095VAC [Ref. 12.1.2] [Ref. 12.1.7] Since the "Low-Low Voltage" setpoint is not associated with a Technical Specification limit, its nominal limits are the "Low Voltage" (Device 27P) and "Loss of Voltage" (Device 27X) setpoints.

File Name: 9000041128 (357S) Rev 1.doc 6/22/2011 CALCULATION NUMBER: 9000041128 REVISION:

1 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 7.12.3. 27H*B2 Undervoltage Setpoint Limit (Loss of Voltage) 23.4VAC Bus Equivalent Setpoint:

23.4 X 34.951 = 818VAC

-

= (23.40 -0.66)VAC = 22.74VAC

+

= (23.40 + 0.66)VAC = 24.06VAC PAGE 48 OF 152 [Ref. 12.1.7]

Minimum Bus Equivalent Setpoint:

22.74VAC X 34.951 = 795VAC Maximum Bus Equivalent Setpoint:

24.06VAC X 34.951 = 841VAC Margin to TS Limit = (795 -O)VAC = 795VAC Margin to TS Limit @ Relay = 795VAC/34.951

= 22.75VAC Limit: ;::: (22.75 -22.75)VAC

OVAC 7.12.4. 27H*B2 Time Delay Setpoint Limit (Low Voltage) 4.7 Sec

+

= (4.7 + 0.32)VAC = 5.02 Sec Margin to TS Limit = (10.0 -5.02)Sec = 4.98 Sec Limit: S (4.7+4.98)VAC S 9.68 Sec 7.12.5. 27H*B2 Time Delay Setpoint Limit (Loss of Voltage)

0.65 Sec

+

27X = (0.65 + 0.07)VAC = 0.72 Sec Margin to TS Limit = (0.80 -0.72)VAC = 0.08 Sec Limit: S (0.65 + 0.08)VAC S 0.73 Sec File Name: 9000041128 (357S) Rev 1.doc [Ref. 12.1.7] [Ref. 12.1.7] 6/22/2011 CALCULATION NUMBER: 9000041128 REVISION:

1 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 PAGE 49 OF 152 7.12.6. 27H*B2 Undervoltage Acceptable As-Found (AAF) Determination 76.3VAC [Ref. 12.1.7]

Drift: +/-0.50VAC [see section 7.5.1]

MTE Effect: +/-0.27VAC [see section 7.4.1]

AAF Tolerance:

+/-(DR + MTE) = +/-(0.50+0.27)VAC

= +/-0.77VAC Since this value is less than the Rack Calibration Accuracy RCA, the acceptable as found tolerance will be +/-1.53 VAC.

Acceptable As-Found Range: 74.77 to 77.83 VAC 30.6VAC Drift: +/-0.3VAC MTE Effect:

+/-0.24VAC [Ref. 12.1.7] [see section 7.5.1] [see section 7.4.1]

AAF Tolerance:

+/-(DR + MTE) = +/-(0.30+0.24)VAC

= +/-0.54VAC Since this value is less than the Rack Calibration Accuracy RCA, the acceptable as found tolerance will be +/-0.61 VAC.

Acceptable As-Found Range: 29.99 to 31.21 VAC 23.4VAC Drift = +/-0.40VAC MTE Effect = +/-0.24VAC [Ref. 12.1.7] [see section 7.5.1] [see section 7.4.1]

AAF Tolerance:

+/-(DR + MTE) = +/-(0.40+0.24)VAC

= +/-0.64VAC Acceptable As-Found Range: 22.76 to 24.04 VAC File Name: 9000041128 (3578) Rev 1.doc 6/22/2011 CALCULATION NUMBER: 9000041128 REVISION:

1 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 7.12.7. 27H*B2 Time Delay Acceptable As-Found (AAF) Determination Setpoint:

4.7 Sec Setpoint Drift: +/-0.1 Sec MTE Effect: +/-O. 0003 Sec PAGE 50 OF 152 [Ref. 12.1.7] [see section 7.S.2] [see section 7.4.2]

AAF Tolerance:

+/-(DR + MTE) = +/-(0.1 +0.0003)Sec

= +/-0.1 0 Sec Since this value is less than the Rack Calibration Accuracy RCA, the acceptable as found tolerance will be +/-0.3 sec.

Acceptable As-Found Range: 4.40 to S.O Sec Setpoint:

1.9 Sec Setpoint Drift: +/-O.OS Sec MTE Effect: +/-0.0002 Sec [Ref. 12.1.7] [see section 7.S.2] [see section 7.4.2]

AAF Tolerance:

+/-(DR + MTE) = +/-(0.OS+0.0002)Sec

= +/-O.OS Sec Since this value is less than the Rack Calibration Accuracy RCA, the acceptable as found tolerance will be +/-0.1 sec.

Acceptable As-Found Range: 1.80 to 2.00 Sec Setpoint:

0.6S Sec Setpoint Drift = +/-O.OS Sec MTE Effect = +/-O. 000 1 Sec [Ref. 12.1.7] [see section 7.S.2] [see section 7.4.2]

AAF Tolerance:

+/-(DR + MTE) = +/-(0.OS+0.0001)Sec

= +/-O.OSSec Acceptable As-Found Range: 0.60 to 0.70 Sec File Name: 9000041128 (357S) Rev 1.doc 6/22/2011 CALCULATION NUMBER: 9000041128 REVISION:

1 PAGE 51 OF 152 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 7.12.8. 27H*T1A Undervoltage Setpoint Limit (Low Voltage) STp DO: 96.5VAC PT Ratio: 34.951 [Heavily burdened transformers on all three phases per Attachment 1] STp DO Bus Equivalent Setpoint:

96.5 X 34.951 = 3373VAC STp DO -

= (96.5 -0.75)VAC

= 95.75VAC STp DO Min. Bus Equivalent STP: 95.75VAC X 34.951 = 3347VAC STp DO Margin to Analytical Limit = (3347-3328)VAC = 19VAC STp DO Margin to Analytical Limit @ Relay = 19VAC/34.951

= 0.54VAC STp DO Limit: (96.5 -0.54)VAC 95.96VAC 7.12.9. 27H*T1 B Undervoltage Setpoint Limit (Low-Low Voltage) STp DO: 90.5VAC PT Ratio: 34.951 [Heavily burdened transformers on all three phases per Attachment 1] STpDO Bus Equivalent Setpoint:

90.5 X 34.951 = 3163VAC STpDO -

= (90.5 -0.72)VAC = 89.78VAC STpDO Min. Bus Equivalent STP: 89.78VAC X 34.951 = 3138VAC STpDO Margin to Analytical Limit = (3138 -3120)VAC = 18VAC STpDO Margin to Analytical Limit @ Relay = 18VAC/34.951

= 0.52VAC I STp DO Limit: "(90.5 -0.52)VAC "89.98VAC 7.12.1 0.27H*T1 C Undervoltage Setpoint Limit (Loss of Voltage) STpDO: 78.6VAC PT Ratio: 34.951 [Heavily burdened transformers on all three phases per Attachment 1] STpDO Bus Equivalent Setpoint:

78.6 X 34.951 = 2747VAC STpDO -

= (78.6 -0.69)VAC = 77.91VAC STpDO Min. Bus Equivalent STP: 77.91VAC X 34.951 = 2723VAC File Name: 9000041128 (357S) Rev 1.doc 6/22/2011 CALCULATION NUMBER: 9000041128 REVISION:

1 PAGE 52 OF 152 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 STp DO Margin to Analytical Limit = (2723 -2704)VAC = 19VAC STp DO Margin to Analytical Limit @ Relay = 19VAC/34.951

= 0.54VAC STp DO Limit: ;::= (78.6 -0.54)VAC ;::= 78.06VAC 7.12.11.27H*T1A Undervoltage Acceptable As-Found (AAF) Determination

96.5VAC Drift: +/-0.34VAC MTE Effect: +/-0.28VAC [see section7.5.3]

[see section7.4.3]

AAF Tolerance:

+/-(DR + MTE) = +/-(0.34+0.28)VAC

= +/-0.62VAC Acceptable As-Found Range: 95.88 to 97.12 VAC 7.12.12.27H*T1 B Undervoltage Acceptable As-Found (AAF) Determination 90.5VAC Drift: +/-0.31VAC MTE Effect: +/-0.28VAC [see section7.5.5]

[see section7.4.4]

AAF Tolerance:

+/-(DR + MTE) = +/-(0.31+0.28)VAC

= +/-0.59VAC Acceptable As-Found Range: 89.91 to 91.09 VAC 7.12.13.27H*T1 C Undervoltage Acceptable As-Found (AAF) Determination 78.6VAC Drift: +/-0.27VAC MTE Effect: +/-0.27VAC [see section7.5.7]

[see section7.4.5]

AAF Tolerance:

+/-(DR + MTE) = +/-(0.27+0.27)VAC

= +/-0.54VAC Acceptable As-Found Range: 78.06 to 79.14 VAC 7.12.14.27H*T1A Time Delay Setpoint Limit (Low Voltage) STpTD: 8.0 sec STpTD +

= (8.0 + 1.02)sec = 9.02 sec STpTD Margin to Analytical Limit = (10-9.02)sec = 0.98sec File Name: 9000041128 (357S) Rev 1.doc 6/22/2011 CALCULATION NUMBER: 9000041128 REVISION:

1 PAGE 53 OF 152 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 STp TD Limit: (8.0 + 0.98)sec 8.98sec 7.12.15.27H*T1 B Time Delay Setpoint Limit (Low-Low Voltage) STp TD: 5.0 sec STp TD +

= (5.0 + 0.72)sec = 5.72 sec STp TD Margin to Analytical Limit = (6 -5.72)sec = 0.28sec STp TD Limit: (5.0 + 0.28)sec 5.28sec 7.12.16.27H*T1C Time Delay Setpoint Limit (Loss of Voltage) STpTD: 3.0 sec STpTD +

= (3.0 + 0.53) sec = 3.53 sec STpTD Margin to Analytical Limit = (4 -3.53) sec = 0.47sec STpTD Limit: (3.0 + 0.47) sec 3.47sec 7.12.17 .27H*T1 A Time Delay Acceptable As-Found (AAF) Determination

8.0 sec Drift: +/-0.18 sec [see section7.5.4]

MTE Effect: +/-0.01 sec [see section7.4.6]

AAF Tolerance:

+/-(DR + MTE) = +/-(0.18+0.01 )sec = +/-0.19sec Since this value is less than the Rack Calibration Accuracy RCA, the acceptable as found tolerance will be +/-1.0 sec.

Acceptable As-Found Range: 7.00 to 9.00 sec 7.12.18.27H*T1 B Time Delay Acceptable As-Found (AAF) Determination 5.0 sec Drift: +/-0.18 sec MTE Effect: +/-0.01 sec [see section7.5.6]

[see section 7.4.7]

AAF Tolerance:

+/-(DR + MTE) = +/-(0.18+0.01)sec

= +/-0.19sec Since this value is less than the Rack Calibration Accuracy RCA, the acceptable as found tolerance will be +/-0.7 sec File Name: 9000041128 (357S) Rev 1.doc 6/22/2011 CALCULATION NUMBER: 9000041128 REVISION:

1 PAGE 54 OF 152 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 Acceptable As-Found Range: 4.30 to 5.70 sec 7 .12.19.27H*T1 C Time Delay Acceptable As-Found (AAF) Determination

3.0 sec Drift: +/-0.18 sec MTE Effect: +/-O. 0 1 sec [see section7.5.8]

[see section7.4.8]

AAF Tolerance:

+/-(DR + MTE) = +/-(0.18+0.01 )sec = +/-0.19sec Since this value is less than the Rack Calibration Accuracy RCA, the acceptable as found tolerance will be +/-0.5 sec Acceptable As-Found Range: 2.50 to 3.50 sec 7.12.20.27H*T2 Undervoltage Setpoint Limit (Instantaneous)

STp DO: 98.0VAC PT Ratio: 35.182 [Bus F is most conservative per Attachment 1] STp DO Bus Equivalent Setpoint:

98.0 X 35.182 = 3448VAC STp DO -

= (98.0 -0.75)VAC = 97.25VAC STp DO Min. Bus Equivalent STP: 97.25VAC X 35.182 = 3422VAC STpDO Margin to Analytical Limit = (3422 -3411)VAC = 11VAC STpDO Margin to Analytical Limit @ Relay = 11VAC/35.182

= 0.31VAC STpDO Limit: (98.0 -0.31)VAC 97.69VAC 7.12.21.27H*T2 Undervoltage Acceptable As-Found (AAF) Determination

98.0VAC Drift: +/-0.34VAC MTE Effect: +/-0.28VAC [see section7.5.9]

[see section7.4.9]

AAF Tolerance:

+/-(DR + MTE) = +/-(0.34+0.28)VAC

= +/-0.62VAC Acceptable As-Found Range: 97.38 to 98.62 VAC 7.12.22.27H*83 Undervoltage Setpoint Limit (Low Voltage) 109.25 VAC File Name: 9000041128 (357S) Rev 1.doc 6/22/2011 CALCULATION NUMBER: 9000041128 REVISION:

1 PAGE 55 OF 152 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 PT Ratio: 34.951 Bus Equivalent Setpoint:

109.25 X 34.951 = 3818VAC

-

= (109.25 -0.78)VAC = 108.47VAC

[Attachment "1"]

Min. Bus Equivalent STP: 108.47VAC X 34.951 = 3791VAC Technical Specification Limit: 3785VAC Margin to TS Limit = (3791 -3785)VAC = 6VAC Margin to TS Limit @ Relay = 6VAC/34.951

= 0.17VAC Limit: (109.25 -0.17)VAC 109.08VAC 7.12.23.27H*B3 Undervoltage Acceptable As-Found (AAF) Determination 109.25VAC

[Ref. 12.1.3]

Drift: +/-0.37VAC MTE Effect: +/-0.29VAC [see section7.5.11]

[see section 7.4.11]

AAF Tolerance:

+/-(DR + MTE) = +/-(0.37+0.29)VAC

== +/-0.66VAC Acceptable As-Found Range: 108.59 to 109.91 VAC 7.12.24.27H*B4 Undervoltage Setpoint Limit (Low Voltage)

109.25 VAC Worst Case PT Ratio: 35.182 [Attachment "1"]

Bus Equivalent Setpoint:

109.25 X 35.182 = 3843VAC

-

= (109.25 -0.78)VAC = 108.47VAC Min. Bus Equivalent STP: 108.47VAC X 35.182 = 3816VAC Technical Specification Limit: 3785VAC Margin to TS Limit = (3816 -3785)VAC = 31VAC Margin to TS Limit @ Relay = 31VAC/35.182

= 0.89VAC Limit: (109.25 -0.89)VAC 108.36VAC 7.12.25.27H*B4 Undervoltage Acceptable As-Found (AAF) Determination 109.25VAC File Name: 9000041128 (357S) Rev 1.doc [Ref. 12.1.3] 6/22/2011 CALCULATION NUMBER: 9000041128 REVISION:

1 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 Drift: +/-0.37VAC MTE Effect:

+/-0.29VAC PAGE 56 OF 152 [see section 7.5.13] [see section 7.4.13]

AAF Tolerance:

+/-(DR + MTE) = +/-(0.37+0.29)VAC

== +/-0.66VAC Acceptable As-Found Range: 108.59 to 109.91 VAC 7.12.26.62H*3A Time Delay Setpoint Limit 8.5 Sec

+

= (8.5 + 0.25) Sec = 8.75 Sec Margin to TS Limit = (10-8.75) Sec = 1.25 Sec Limit: (8.5 + 1.25)VAC 9.75 Sec 7.12.27.62H*3A Time Delay Acceptable As-Found (AAF) Determination 8.5 Sec Drift: +/-0.17 Sec MTE Effect: +/-0.01 Sec [see section 7.5.15] [see section 7.4.15]

AAF Tolerance:

+/-(DR + MTE) = +/-(0.17+0.01 )Sec == +/-0.18 Sec Acceptable As-Found Range: 8.32 to 8.68 Sec 7.12.28.62H*38 Time Delay Setpoint Limit 18.5 Sec

+

= (18.5 + 0.54) Sec = 19.04 Sec Margin to TS Limit = (20 -19.04) Sec = 0.96 Sec Limit: (18.5 + 0.96)VAC 19.46 Sec 7.12.29.62H*38 Time Delay Acceptable As-Found (AAF) Determination 18.5 Sec Drift: +/-0.37 Sec MTE Effect:

+/-0.01 Sec [see section 7.5.16] [see section 7.4.16] File Name: 9000041128 (357S) Rev 1.doc 6/22/2011 CALCULATION NUMBER: 9000041128 REVISION:

1 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 PAGE 57 OF 152 AAF Tolerance:

+/-(DR + MTE) = +/-(O.37+0.01)Sec

= +/-O.38Sec Acceptable As-Found Range: 18.12 to 18.88 Sec File Name: 9000041128 (357S) Rev 1.doc 6/22/2011 CALCULATION NUMBER: 9000041128 REVISION:

1 PAGE 58 OF 152 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 7.12.30.SLUR Dropout Avoidance Limit 83 dropout voltage is 3818VAC (Typical) with an uncertainty of 27.36V (0.78*34.951).

The standard deviation of uncertainty

= 27.36/1.96

= 13.96V The highest 84 dropout voltage is related to 8us "G" with a setpoint of 3855V and an uncertainty of 27.63V (0.78V*35.287).

The standard deviation of uncertainty

= 27.63V/1.96

= 14.10V Since both relays must actuate for the dropout function, we have to find the highest voltage at which there is more than 50/0 probability that both relays will actuate. Graphically under the normal distribution curve, the product of Area "A" and "8" should be less than 0.05. > > co I.t') -I.t') co co M M 0.03 0.025 0.02 0.015 0.01 0.005 0 3650 3700 3750 3800 3850 ---83 Typical At 3840V the probability of 83 actuating is: Z = (3840-3818) 113.96 = 1.58 This "z" value corresponds to 5.710/0 probability At 3840V the probability of 84 actuating is: Z = (3840 -3855) 114.10 = -1.06 3900 3950 4000 4050 --2-27HGB4 Since the Z value is negative, the probability will be 50%) + (500/0 -probability of absolute value of Z value 1.06). This "Z" value corresponds to 14.46% probability Hence the probability of 84 actuating at 3840 is 50% + 500/0 -14.46% = 85.54% The probability of both 83 and 84 actuating is 5.71 %

  • 85.54% = 4.90/0 File Name: 9000041128 (3578) Rev 1.doc 6/22/2011 CALCULATION NUMBER: 9000041128 REVISION:

1 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 Therefore:

PAGE 59 OF 152 I The SLUR Trip Avoidance Limit is 3840V or 92.31 % of bus rated voltage File Name: 9000041128 (357S) Rev 1.doc 6/22/2011 CALCULATION NUMBER: 9000041128 REVISION:

1 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 7.13. Maximum Pickup Voltage (Reset) 7.13.1. 27H*B2 Diesel Start Reset PAGE 60 OF 152 Per Attachment 11, the lowest reset dropout ratios for B2 diesel start function are as follows: Device Average Dropout Ratio Lower Limit of Dropout Ratio 1/2-27H*B2

-27P 0.98127 0.97670 1/2-27H*B2

-127P 0.98066 0.97653 1/2-27H*B2

-27X 0.98104 0.97527 Setpoint and Reset Voltage for Diesel Start (27P) Bus Voltage (VAC) Setpoint for Diesel Start in 4.7 Sec: 2667 Average Reset for Diesel Start in 4.7 Sec: 2718 (2667/0.98127)

Maximum Setpoint for Diesel Start in 4.7 Sec: [STP + CU*(1.645/1.96)]

(95% confidence limit single Sided) 2715 2667 + (1.632*34.951

)*(1.645/1.96)

Maximum Reset Voltage for Diesel Start in 4.7 Sec: 2780 (2715/0.97670)

Setpoint and Reset Voltage for Diesel Start (127P) Bus Voltage (VAC) Setpoint for Diesel Start in 1.9 Sec: 1070 Average Reset for Diesel Start in 1.9 Sec: 1091 (1070/0.98066)

Maximum Setpoint for Diesel Start in 1.9 Sec: [STP + CU*(1.645/1.96)]

(95% confidence limit single Sided) 1091 1070 + (0.722*34.951

)*(1.645/1.96)

Maximum Reset Voltage for Diesel Start in 1.9 Sec: 1117 (1091/0.97653)

File Name: 9000041128 (357S) Rev 1.doc 6/22/2011 CALCULATION NUMBER: 9000041128 REVISION:

1 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 Setpoint and Reset Voltage for Diesel Start (27X) Setpoint for Diesel Start in 0.65 Sec: Average Reset for Diesel Start in 0.65 Sec: (818/0.98104)

Maximum Setpoint for Diesel Start in 0.65 Sec: [STP + CU*(1.645/1.96)]

(95% confidence limit single Sided) 818 + (0.662*34.951)*(1.645/1.96)

Maximum Reset Voltage for Diesel Start in 0.65 Sec: (837/0.97527)

File Name: 9000041128 (3578) Rev 1.doc PAGE 61 OF 152 Bus Voltage (VAe) 818 834 838 859 6/22/2011 CALCULATION NUMBER: 9000041128 REVISION:

1 PAGE 62 OF 152 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 7.13.2. 27H*T1 & 27H*T2 Load Shed Reset Since for the Load Shed reset a "1-out-of-2" logic is employed, the T1 relays will reset sooner than the T2 due to their lower setpoints (and thus reset points). Per assumption 3.7, the ABB 27N and 59N relays allow for setting the Dropout (Actuate) setting as a percentage of the Pickup (Reset) setting. This calculation has taken the position of calculating a setpoint for the dropout of the relays and the pickup will be calculated as a percentage of the dropout setting. Accordingly, this calculation assumes that the uncertainty impacts the dropout setting and that the dropout and pickup settings will drift together in the same direction and not independently of each other. Hence there will be no additional uncertainty applied to the pickup setting. Reset of the FLUR Load Shed will only occur once 27H*T1A has reset. Since the reset of 27H*T1 A will be set as a percentage of the dropout, it is conservative to assume the highest dropout voltage for 27H*T1A. Highest dropout = 96.5 + .75VAC = 97.25VAC The dropout will be set at 99% of the pickup setting. Hence pickup will be: Highest pickup = 97.25VAC /99% = 98.24VAC This corresponds to a bus voltage of 98.24 x 34.951 = 3433VAC The highest bus voltage that a reset will occur by a T1 A device is 3433V or 82.52%. Reset of the FLUR Load Shed will only occur once 27H*T1 B has reset. Since the reset of 27H*T1 8 will be set as a percentage of the dropout, it is conservative to assume the highest dropout voltage for 27H*T1 B. Highest dropout = 90,5 + .72VAC = 91.22VAC The dropout will be set at 99% of the pickup setting. Hence pickup will be: Highest pickup = 91.22VAC /990/0 = 92.14VAC This corresponds to a bus voltage of 92.14 x 34.951 = 3220VAC The highest bus voltage that a reset will occur by a T1 B device is 3220V or 77.41%. Reset of the FLUR Load Shed will only occur once 27H*T1 C has reset. Since the reset of 27H*T1 C will be set as a percentage of the dropout, it is conservative to assume the highest dropout voltage for 27H*T1 C. Highest dropout = 78.6 + .69VAC = 79.29VAC The dropout will be set at 990/0 of the pickup setting. Hence pickup will be: Highest pickup = 79.29VAC /990/0 = 80.09VAC This corresponds to a bus voltage of 80.09 x 34.951 = 2799VAC The highest bus voltage that a reset will occur by a T1 C device is 2799V or 67.29%. File Name: 9000041128 (357S) Rev 1.doc 6/22/2011 CALCULATION NUMBER: 9000041128 REVISION:

1 PAGE 63 OF 152 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 7.13.3. SLUR Diesel Start & Load Shed Reset The setpoints for SLUR undervoltage relays (27H*83 & 27H*B4) are selected such that the corresponding bus voltage will be as close to each other as possible.

Therefore, in calculating the "1-out-0-2" logic, a voltage must be selected that the probability of at least one relay resetting will equate to 950/0. This is accomplished using the following procedure:

(1) The setpoints both at the relay and corresponding voltages on the bus, channel uncertainty and pickup ratio are tabulated in the following tables. (2) The expected average reset is equal to the device setpoint divided by the average pickup ratio for that device. (3) The highest reset is related to the uncertainty associated with the pickup ratio. In the previous revision of this calculation an uncertainty of 0.59% was calculated for the existing Westinghouse hardware.

In this calculation, for the purpose of conservatism an uncertainty of 0.7% will be assumed for the new ABB relay. (4) For each pair of devices a voltage is selected.

The difference between this selected value and the highest reset voltage calculated in step 3 divided by the standard deviation of uncertainty will provide us with the "z" value for the standard Gaussian table. The calculated uncertainty of the drop out (CU DO) is calculated at 95% confidence level for a two sided distribution (Le.; 1.96 X cr). The standard deviation of error is calculated for each device by dividing the dropout uncertainty by 1.96. (5) Using the standard Gaussian distribution table the probability for each "Z" value is obtained.

The probability of each device not resetting is the area under normal distribution curve corresponding to this "z" value. The probability of each device not resetting is calculated.

The probability of neither devices resetting is the product of the probability of each device not resetting.

The selected voltage will be adjusted till the probability of neither device resetting is less than 50/0. The probability of at least one device resetting is equal to one minus this latter value. The result of the above procedure is tabulated in the following tables: File Name: 9000041128 (357S) Rev 1.doc 6/22/2011 CALCULATION NUMBER: 9000041128 REVISION:

1 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 PAGE 64 OF 152 Units 1 &2, Second Level Undervoltage Relay (SLUR) Reset Summary Device 27HFB3 27HFB4 27HGB3 27HGB4 27HHB3 27HHB4 Setpoint @ Relay 109.25 109.25 109.25 109.25 109.25 109.25 PT Ratio 34.951 35.182 34.951 35.287 34.951 35.224 Setpoint @ 4KV Bus 3818 3844 3818 3855 3818 3848 Relay Uncertainty 0.78 0.78 0.78 0.78 0.78 0.78 Uncertainty

@ Bus 27 27 27 28 27 27 Standard Deviation of 13.9 14.0 13.9 14.0 13.9 14.0 Uncertainty

@ Bus Pickup (Reset) Ratio 0.99 0.99 0.99 0.99 0.99 0.99 Average Reset Point (V AC) 3857 3882 3857 3894 3857 3887 Highest Reset (V AC) 3884 3910 3884 3922 3884 3915 Setpoint (% Bus Voltage) 91.79% 92.40% 91.79% 92.67% 91.79% 92.51%

Highest Rest (% Bus Voltage) 93.37% 93.99% 93.37% 94.27% 93.37%

94.10% Voltage corresponding to 95% 3877 3879 3878 Reset % Bus Voltage corresponding 93.20% 93.25% 93.22% to 95 % Reset Z Value 1.44 -0.39 1.58 -1.07 1.51 -0.65 Probability Not Resetting 7.49% 65.17% 5.71% 85.77% 6.55% 74.22% Probability of 1-out-of-2 Reset 95.l2% 95.10% 95.14% File Name: 9000041128 (357S) Rev 1.doc 6/22/2011 CALCULATION NUMBER: 9000041128 REVISION:

1 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011

8. Results: Presented graphically as follows Undervoltage Function 3474V 3399V 7 3448 VAG T2 STP; AAF 3469V } I 3394V } 3426V 3373 VAG AAF AL-_ 3411 VAC 3421V t ... 3347V t------... AL: 3328 VAC t M = 19 V 3188V 3163 VAC T1B3::V J;:::: }AAF AL: 3120VAC IM=18V 2771V 2766V } 2747 VAC T1CSTP E: ! AAF 2723V AL: 2704 VAC 1M = 19 V 2667 VAG B2*27P STP 2724V12720V}AAF

! 2613V T5 Limit: 2583 VAC _____ .26.1.0.V.l

..

______ _ 1070 VAG 818 VAC T5 Limit: 0 VAC 1095V .-A ... __

____________

__ 1091V} 104SilQ:4l111.

AAF 841V 840V } B2*27X STP AAF I 796V 795V**** *-T***********************

1 M=795V File Name: 9000041128 (357S) Rev 1.doc PAGE 65 OF 152 Time Delay Function Limit =10.0Sec Margin =0.98Sec Max STP: 9.02 Sec cU =1.02Sec STP: 8.0 Sec T1A Time Delay Limit =6.0 Sec Margin =0.28Sec Max STP: 5.72 Sec CU =O.72Sec STP: 5.0 Sec T1 B Time Delay Limit =4.0 Sec Margin =0.53 Sec Max STP: 3.53 Sec CU =O.53Sec STP: 3.0 Sec T1 G Time Delay TS Limit = 10 Sec Margin = 4.98 Sec Max STP: 5.02 Sec CU =0.32 Sec STP: 4.7 Sec 27P Time Delay TS Limit = O.S Sec Margin = 0.08 Sec Max STP: 0.72 Sec CU =0.07 Sec STP: 0.65 Sec 27X Time Delay 6/22/2011 CALCULATION NUMBER: 9000041128 REVISION:

1 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 SLUR Setpoints 3871V PAGE 66 OF 152 3843 VAC AAF 3866V} 84STP 3818 VAC 3846V . 83STP AAF 'I 3841V } I 3795V 3791V 't M=31V t M=6V TS Limit: 3785 VAC ___

  • __________

IIIIIIi __ _ TS Limit Load Shed: 20 Sec _______ ..... ________ _ l 18.5 Sec 19.04 Sec .YA . / i 18.88 sec} 38 Time Delay STP ..L i **1 AAF 118.12 Sec 17.96 Sec "r***** TS Limit Diesel Start: 10 Sec _______ ... _________

_ I M = 1.25 sec 8.75 Sec . +A /1 8.68 Sec } 8.5 Sec 3A Time Delay Setpoint/'m

........ ! . I AAF a.32See 8.25 Sec ........ , Note: This graph represents the worst case uncertainty and not a typical value File Name: 9000041128 (357S) Rev 1.doc 6/22/2011 CALCULATION NUMBER: 9000041128 REVISION:

1 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 Results presented in tabular format: PAGE 67 OF 152 First Level Undervoltage Relay (FLUR) Setpoint Summary >. >. C til >. til ...... = = = = >. .; .; ""1' @ @ 1:: til 1:: @ ...... @tIl @ E <I.i >. ...... ...... Device ...... ...... = '5 ...... = <I.i = = @ '5 . ; = E--'0 '0 Q. J J >. >. 1:: -< Q. <I.i ...... ...... 00. -< <I.i 00. <I.i 00. E--= 00. E--RCA: 1.53 From: 1I2-27H*B2-27P 76.3 34.951 2667 2583 73.90 RMTE: 0.271 1.632 57 74.77 (Undervoltage-V AC) RD: 0.5 To: RTE: 0 77.83 RCA: 0.61 From: 1I2-27H*B2-127P 30.6 34.951 1070 NA NA RMTE: 0.243 0.722 25 29.99 (Undervoltage-VAC)

RD: 0.3 To: RTE: 0 31.21 RCA: 0.5 From: 1I2-27H*B2-27X 23.4 34.951 818 0 0.00 RMTE: 0.239 0.662 23 22.76 (Undervoltage-V AC) RD: 0.4 To: RTE: 0 24.04 RCA: 0.3 From: l/2-27H*B2-27P 4.7 NA 4.7 10 10 RMTE: 0.0003 0.316 0.316 4.40 (Time Delay-Sec)

RD: 0.1 To: RTE: 0 5.0 RCA: 0.1 From: 1I2-27H*B2-127P 1.9 NA 1.9 NA NA RMTE: 0.0002 0.112 0.112 1.80 (Time Delay-Sec)

RD: 0.05 To: RTE: 0 2.0 RCA: 0.05 From: 1I2-27H*B2-27X RMTE: 0.0001 0.60 (Time Delay-Sec) 0.65 NA 0.65 0.8 0.8 RD: 0.05 0.071 0.071 To: RTE: 0 0.70 RCA: 0.5 From: 1I2-27H*TIA RMTE: 0.28 95.88 96.5 34.951 3373 3328 95.2 RD: 0.34 0.75 26 To: (Undervoltage-VAC)

RTE: 0.32 97.12 RME: 0.1 i.....--i..-File Name: 9000041128 (357S) Rev 1.doc 6/22/2011 .s> .s .: =-til ._ <I.i = ;@tIl @ ...... ...... e ..........

.: .5 -< .§ J -< Q.oo. B-oo. lSE--00. From: 2613 27 0.76 To: 2720 From: 1048 NA NA To: 1091 From: 796 795 22.74 To: 840 From: 4.40 4.98 4.98 To: 5.0 From: 1.80 NA NA To: 2.0 From: 0.60 To: 0.08 0.08 0.70 From: 3351 To: 19 0.54 3394 CALCULATION NUMBER: 9000041128 REVISION:

1 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 PAGE 68 OF 152 First Level Undervoltage Relay (FLUR) Setpoint Summary >. C 00 >. >. ::s 00 eo: ...... = >. eo: ::s = .; .; @) eo: .S @) 1:: 00 1:: ...... @)oo @) E c @) eo: I:J @) Device ...... ::s ...... = = = ...... 5 *s ;;;;J . ; = r-'0 :5 ;;;;Jr-1:: '0 :5 >. >. -< Q. Q. eo:: eo: -< "t 00 I:J ...... 00 = r-00 00 r-;;;;J RCA: 0.5 From: RMTE: 0.28 89.91 1I2-27H*TIB 90.5 34.951 3163 3120 89.3 RD: 0.31 0.72 25 To: (Undervoltage-VAC)

RTE: 0.30 91.09 RME: 0.09 RCA: 0.5 From: RMTE: 0.27 78.06 1I2-27H*TIC 78.6 34.951 2747 2704 77.4 RD: 0.27 0.69 24 To: (Undervoltage-VAC)

RTE: 0.26 79.l4 RME: 0.08 RCA: 1.0 From: RMTE: 0.01 7.00 1I2-27H*TIA (Time 8.0 NA 8.0 10.0 10.0 RD: 0.18 1.02 1.02 To: Delay-Sec)

RTE: 0.0 9.00 RME: 0.0 RCA: 0.7 From: RMTE: 0.01 4.30 1I2-27H*TIB (Time 5.0 NA 5.0 6.0 6.0 RD: 0.18 0.72 0.72 To: Delay-Sec)

RTE: 0.0 5.70 RME: 0.0 RCA: 0.50 From: RMTE: 0.01 2.50 1I2-27H*TIC (Time 3.0 NA 3.0 4.0 4.0 RD: 0.18 0.53 0.53 To: Delay-Sec)

RTE: 0.0 3.50 RME: 0.0 File Name: 9000041128 (357S) Rev 1.doc 6/22/2011 -S> o >. ...... eo: .5 =-00 ..... ::s bf) ;@)oo eo:@) @) ...... ......... ...... 5 .5 .5 -< .§ :5 O...:l -< Q.oo :00 "tr-00 From: 3142 To: 18 0.51 3184 From: 2728 To: 19 0.55 2766 From: 7.00 To: 0.98 0.98 9.00 From: 4.30 To: 0.28 0.28 5.70 From: 2.50 To: 0.47 0.47 3.50 I I I CALCULATION NUMBER: 9000041128 REVISION:

1 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 PAGE 69 OF 152 First Level Undervoltage Relay (FLUR) Setpoint Summary >. C C >. = eo:! = eo:! = = >. .; .; eo:! @ ..... @ @ 1: 1: C @ eo:! E ;t:: c:.I Device ..... ..... = ..... = = = @ = E--5 '5 0; '0 '0 :3 1: :3 >. >. -< 0. 0. eo:! eo:! ..... 00 c:.I -< 00 E--00 = 00 E--RCA: 0.5 From: RMTE: 0.28 97.38 1I2-27HFT2 98.0 35.182 3448 3411 96.95 RD: 0.34 0.75 26 To: (Undervoltage-VAC)

RTE: 0.32 98.62 RME: 0.10 RCA: 0.5 From: RMTE: 0.28 97.38 1I2-27HGT2 98.0 35.287 3458 3411 96.66 RD: 0.34 0.75 26 To: (Undervoltage-VAC)

RTE: 0.32 98.62 RME: 0.10 RCA: 0.5 From: RMTE: 0.28 97.38 1I2-27HHT2 98.0 35.224 3452 3411 96.84 RD: 0.34 0.75 26 To: (Undervoltage-VAC)

RTE: 0.32 98.62 RME: 0.10 File Name: 9000041128 (357S) Rev 1.doc 6/22/2011 3> 3 .5 =-.-= eJ) ;@(IJ eo:!@ @ ..... ..... 5 ...... --< .§ :3 = 5 .JIIIIIIIII

.,.,... -<

0.00 ..... 00 00 From: 3426 To: 11 0.31 3470 From: 3436 To: 21 0.60 3480 From: 3430 To: 15 0.42 3474 CALCULATION NUMBER: 9000041128 REVISION:

1 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 PAGE 70 OF 152 Second Level Undervoltage Relay (SLUR) Setpoint Summary Device RCA: 0.50 From: From: RMTE: 0.29 108.59 3795 0.17 1I2-27HF/GIHB3 109.25 34.951 3818 3785 108.29 1------1 RD: 0.37 0.78 27 6 To: To: RTE: 0.36 RME: 0.11 109.91 3841 RCA: O.ll From: From:

1-----1 RMTE: 0.50 108.59 3820 1I2-27HFB4 109.25 35.182 3844 3785 107.58 RD: 0.37 0.78 28 To: To: 31 0.89 RTE: 0.36 RME: O.ll 109.91 3867 RCA: 0.50 From: From:

RMTE: 0.29 108.59 3832 1I2-27HGB4 109.25 35.287 3855 3785 107.26 RD: 0.37 0.78 28 To: To: 42 1.20 RTE: 0.36 RME: 0.11 109.91 3878 RCA: 0.50 From: From:

RMTE: 0.29 108.59 3825 1I2-27HHB4 109.25 35.224 3848 3785 107.46 RD: 0.37 0.78 28 To: To: 35 1.00 RTE: 0.36 RME: 0.11 109.91 3871 RCA: 0.05 From: From:

RMTE: 0.01 8.32 8.32 1I2-62HF/G1H3A 8.5 NA 8.5 10.0 10.00 RD: 0.17 0.25 0.25 To: To: 1.25 1.25 RTE: 0.05 RME: 0.17 8.68 8.68 RCA: 0.1 From: From: 1-----1 RMTE: 0.01 18.12 18.12 1-----1 RD: 0.37 0.96 1I2-62HF IG/H3B 18.5 NA 18.5 20.0 20.00 0.54 0.54 0.96 To: To: RTE: 0.11 RME: 0.37 18.88 18.88 File Name: 9000041128 (357S) Rev 1.doc 6/22/2011 CALCULATION NUMBER: 9000041128 REVISION:

1 PAGE 71 OF 152 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 Inputs to other Calculations FLUR 2/2 T1A&T2 Logic Load Shed Lowest Voltage: 3351V or 80.55% < 8.86 sec [Section 7.9] FLUR 2/2 T1 B& T2 Logic Load Shed Lowest Voltage: 3142V or 75. 5% < 5.60 sec [Section 7.9] FLUR 2/2 T1 C& T2 Logic Load Shed Lowest Voltage: 2727V or 65.550/0 < 3.44 sec [Section 7.9] FLUR 1/2 T1A &T2 Logic Load Shed Maximum Reset Voltage: 3433V or 82.52% [section 7.13.2] FLUR 1/2 T1 B &T2 Logic Load Shed Maximum Reset Voltage: 3220V or 77.41 % [section 7.13.2] FLUR 1/2 T1C &T2 Logic Load Shed Maximum Reset Voltage: 2799V or 67.29% [section 7.13.2] FLUR 2/2 T1A & T2 Load Shed Trip Avoidance Limit: 3395V or 81.61 % [Section7.9]

FLUR 2/2 T1 B & T2 Load Shed Trip Avoidance Limit: 3184V or 76.54% [Section7.9]

FLUR 2/2 T1 C & T2 Load Shed Trip Avoidance Limit: 2767V or 66.52% [Section 7.9] FLUR Diesel Start Minimum & Maximum Bus Voltage B2-27P: Setpoint = 2667V Bus Voltage (64.100/0)

[Section 7.12.1] From 2610V to 2724 (62.73% to 65.48%), EDG starts within 4.7 Sec +/-O.32 Sec B2-127P: Setpoint = 1070V Bus Voltage (25.71 %) [Section 7.12.2] From 1 044V to 1095V (25.10% to 26.32%), EDG starts within 1.9 Sec +/-0.11 Sec B2-27X: Setpoint = 818V Bus Voltage (19.66%) [Section 7.12.3] From 795V to 841 (19.11 % to 20.22%), EDG starts within 0.65 Sec +/-0.07 Sec FLUR Diesel Start Maximum Reset Voltage -Section 7.13.1 B2-27P: 2780V or 66.380/0 bus voltage B2-127P: 1117V or 26.85% bus voltage B2-27X: 859V or 20.65% bus voltage SLUR 2/2 Logic for Diesel Start & Load Shed Lowest Voltage -Section 7.10 3791 V or 91.13% bus voltage SLUR 1/2 Logic Diesel Start & Load Shed Maximum Reset Voltage -Section 7.13.3 3879V or 93.250/0 bus voltage File Name: 9000041128 (3578) Rev 1.doc 6/22/2011 CALCULATION NUMBER: 9000041128 REVISION:

1 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 03/22/2011 SLUR 2/2 Trip Avoidance Limit -Section 7.12.30 3840V or 92.31% bus voltage SLUR Timer Min & Max Timeout EDG Start Setpoint = 8.5Sec +/- 0.25Sec [Section 7.12.26] Single sided uncertainty (CU

  • 1.645/1.96)

= -0.21 Sec OR +0.21 Sec Load Shed Actuation

= 18.5Sec +/- 0.54Sec [Section 7.12.28] Single sided uncertainty (CU

  • 1.645/1.96)

= -0.45Sec OR +0.45Sec File Name: 9000041128 (357S) Rev 1.doc PAGE 72 OF 152 6/22/2011 CALCULATION NUMBER: 9000041060 REVISION:

1 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 01/12/2011

9. Margin Assessment FLUR Setpoints Device Setpoint TS Limit 27H*82-27X 23.4 VAG @ 0.65 Sec OVAG @ <0.8 Sec 27H*82-27P 76.3 VAC @ 4.7 Sec 2583VAC @ <10 Sec 27H*T1A 96.5 VAC @ 8.0 Sec 3328VAC @ < 10 Sec 27H*T1B 90.5 VAC @ 5.0 Sec 3120VAC @ < 6 Sec 27H*T1C 78.6 VAC @ 3.0 Sec 2704VAC @ < 4 Sec 27H*T2 98.0 VAC instantaneous 3411 VAC instantaneous SLUR Setpoints Device Setpoint TS Limit 27H*83 109.25 VAG 3785 VAG 27H*84 109.25 VAC 3785 VAC 62H*3A 8.5 Sec 10 Sec 62H*3B 18.5 Sec 20 Sec File Name: 9000041128 (357S) Rev 1.doc PAGE 73 OF 152 Margin @ Margin @ Relay 4KV Bus 22.74VAG 795 VAG 0.08 Sec 0.08 Sec 0.76VAC 27VAC 4.98 Sec 4.98 Sec 0.54 VAC 19VAC 0.98 Sec 0.98 Sec 0.51 VAC 18VAC 0.28 Sec 0.28 Sec 0.55 VAC 19VAC 0.47 Sec 0.47 Sec 0.31 VAC 11 VAC Margin @ Margin @ Relay 4KV Bus 0.17 VAG 6 VAG 0.89VAC 31 VAC 1.25 Sec 1.25 Sec 0.96 Sec 0.96 Sec 6/22/2011 CALCULATION NUMBER: 9000041060 REVISION:

1 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 01/12/2011

10. Conclusion PAGE 74 OF 152 10.1. The FLUR dropout undervoltage and time delay setpoints adequate margin from TS allowable values [Acceptance criteria 6.1]. 10.2. The SLUR dropout undervoltage and time delay setpoints provide adequate margin from TS allowable values [Acceptance criteria 6.2]. 10.3. The adequacy of SLUR and FLUR to protect vital 4kV motors from tripping on an undervoltage event will be evaluated in calculation 170-DC. 10.4. The adequacy of SLUR dropout setpoint to prevent unnecessary and spurious actuation of protection system shall be evaluated in calculation 359-DC. 10.5. The impact of highest SLUR reset voltage on ability to maintain connection to offsite power source will be evaluated in 357 A-DC [Ref. 12.1.56].

10.6. The adequacy of diesel generator time delay shall be evaluated in calculation 357 A-DC. 10.7. The maximum time of 16 seconds established as the acceptance criteria for the load tap change in sections 7.3.8 and 7.5.8 of the electrical maintenance procedure MP E-62.3 [Ref. 12.1.8] provides more than 950/0 probability that the SLUR will not actuate before voltage is recovered by the load tap changer. The SLUR timer uncertainty is 0.54 sec. The standard deviation of uncertainty

= 0.54 sec 11.96 = 0.28 sec. The margin between the nominal setpoint of 18.5 seconds and 16 seconds LTC acceptance criteria is 1 sec or equal to 8.93Z (Z = [18.5 sec-16 sec] 1 stdev). Based on standard normal distribution table, the 8.93Z corresponds to =::; 0.01 %. This means there is greater than a 99.99% probability that the SLUR will not actuate before completion of the third load tap change. File Name: 9000041128 (357S) Rev 1.doc 6/22/2011 CALCULATION NUMBER: 9000041060 REVISION:

1 PAGE 75 OF 152 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 01/12/2011

11. Impact Evaluation 11.1. The change in FLUR Analytical Limits will require a change to Technical Specifications Surveillance Requirements SR 3.3.5.3 as well as the Technical Specification Bases. This change is currently being tracked by notification 50301167 Task 13 and will require submittal of an LAR. 11.2. MP E-50.33A requires revision to remove the FLUR's and SLUR's from the scope of this procedure.

The FLUR's and SLUR's will no longer use SSV-T relays hence this procedure no longer applies to them. This is being tracked by Order 68012804 Operation

30. 11.3. MP E-50.61 requires revision to remove the 27H*T1 relays from the scope of this procedure.

The "T1" relays will not longer use Basler BE 1-27 relays hence this procedure no longer applies to them. This is being tracked by Order 68012804 Operation

40. 11.4. MP E-50.62: The Acceptable As-Found values established in this calculation are based on the historical performance of the undervoltage relays and timers. These values are more restrictive than those used in the calibration procedures.

As-Found setpoints outside the limits established in this calculation could be early sign of relay degradation and should trigger performance monitoring at a higher frequency.

This calibration procedure should be revised to reflect the Acceptable-As-Found values established in this calculation.

This will be tracked by order 68012804 Operation 140. 11.5. STP M-75F, G & H require a complete revision based on the design change to the hardware as well as changes to setpoints and acceptable as-left tolerences via this calculation.

This will be tracked by order 68012804 Operation

50. 11.6. STP M-13F, G & H require revision based on the design change to the hardware as well as changes to setpoints and acceptable as-left tolerences via this calculation.

This will be tracked by order 68012804 Operation

60. 11.7. Calculation 359-0C must be evaluated for impact. Order 68012804 Operation 70 has been created to track evaluation of potential impact on calculation 359-0C. 11.8. Calculation 357R-OC shall be superseded by this calculation.

Order 68012804 Operation 80 has been created to track voiding this calculation.

11.9. Calculation 357A-OC must be evaluated for impact. Order 68012804 Operation 90 has been created to track evaluation of potential impact on calculation 357 A-DC. 11.10. Calculation 170-0C must be evaluated for impact. Order 68012804 Operation 100 has been created to track evaluation of potential impact on calculation 170-0C. 11.11. FSAR section 8.3 will require revision based on the changes in design and per this calculation.

Order 68012804 Operation 110 has been created to track revision FSAR Section 8.3. 11.12. OCM T-18 will require revision based on the changes in design and per this calculation.

Order 68012804 Operation 120 has been created to track revision to OCM T-18. 11.13. OCM S-63 will require revision based on the changes in design and per this calculation.

Order 68012804 Operation 130 has been created to track revision to OCM S-63. File Name: 9000041128 (357S) Rev 1.doc 6/22/2011 CALCULATION NUMBER: 9000041060 REVISION:

1 PAGE 76 OF 152 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 01/12/2011

12. References 12.1. Input

References:

12.1.1. CF6.NE1, Revision 3, Instrument Channel Uncertainty and Setpoint 12.1.2. Technical Specifications 3.3.5 (SR 3.3.5.3.a), Unit 1 Amendment 200, Unit 2 Amendment 201 12.1.3. Technical Specifications 3.3.5 (SR 3.3.5.3.b), Unit 1 Amendment 200, Unit 2 Amendment 201 12.1.4. MP E-50.33A, Rev. 9 12.1.5. MP E-50.30B, Rev. 12 [Agastat Type ETR relay calibration]

12.1.6. MP E-50.61, Rev. 3 [Basler BE1-27 relay calibration]

12.1.7. MP E-50.62, Rev. 4 [Basler BE1-GPS100 relay calibration]

12.1.8. MP E-62.3, Revision 2 [Tap Changer Functional Test for SU Transformer]

12.1.9. STP M-75, Revision 30 12.1.10. OCM T-20, Revision 9A, Table A4.2-1 12.1.11. OCM S-230, Revision 16, Section 4.3.1.g 12.1.12. OCM S-63, Revision 15A (or latest revision) 12.1.13. 437568 R3 12.1.14. 441229 R17 12.1.15. 441340 R29 12.1.16. 445399 R7 12.1 . 17. 441315 R 16 12.1 . 18. 441345 R 17 12.1.19. 441349 R17 12.1.20.441311 R23 12.1.21. 441309 R22 12.1.22. 441307 R16 12.1.23. 441302 R21 12.1.24. 441356 R13 12.1.25. 441230 R26 12.1.26. 441313 R26 12.1.27. 441354 R30 12.1.28. 4008751 R8 12.1.29. 4008756 R8 12.1.30. 437533 R40 12.1.31. 437583 R19 12.1.32. 437589 R16 12.1.33. 437590 R19 12.1.34. 437591 R23 12.1.35. 437593 R31 12.1.36. 437594 R30 12.1.37. 437595 R30 12.1.38. 437600 R31 12.1.39. 437614 R33 12.1.40. 437621 R23 12.1.41. 437626 R32 12.1.42. 437627 R32 12.1.43. 437664 R17 12.1.44. 437666 R30 File Name: 9000041128 (357S) Rev 1.doc 6/22/2011 CALCULATION NUMBER: 9000041060 REVISION:

1 PAGE 77 OF 152 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 01/12/2011 12.1.45. 441287 R26 12.1.46. 441312 R26 12.1.47. 441353 R29 12.1.48. 445077 R3 12.1.49. 496276 R7 12.1.50. 663332-220-1

[Basler BE1-GPS100 Relay Vendor Manual] 12.1.51. [ABB 27N/59N Relay Vendor Manual] 12.1.52. [ABB 62T Relay Vendor Manual] 12.1.53. A0520041 12.1.54. RPE E-07664 12.1.55. Calculation M-447, Rev. 1 12.1.56. Calculation 357 A-DC, Rev 12 (SAP 9000033359-00-012) 12.1.57. Determination of setpoint span by ABB. E-mail. See Attachment

12. 12.1.58. Calculation 170-DC 12.1.59. Calculation 9000041185 "Voltage Study of Vital 480VAC Loads" 12.1.60. Calculation 9000041186 "Voltage Study of Vital Fuse Loads" 12.2. Output

References:

12.2.1. STP M-75 12.2.2. STP M-13F/G/H 12.2.3. MP E-50.33A 12.2.4. MP E-50.61 12.2.5. MP E-50.62 12.2.6. DCM S-63 12.2.7. DCM T-18 12.2.8. Calculation 357A-DC 12.2.9. Calculation 359-DC 12.2.10.Calculation 170-DC 12.2.11.Calculation 9000041185 "Voltage Study of Vital 480VAC Loads" 12.2.12.Calculation 9000041186 "Voltage Study of Vital Fuse Loads" 12.3. Other

References:

12.3.1. Notification 50301167 File Name: 9000041128 (357S) Rev 1.doc 6/22/2011 CALCULATION NUMBER: 9000041060 REVISION:

1 PAGE 78 OF 152 CALCULATION TITLE: 4.16 kV Bus FLUR & SLUR Setpoint Calculation DATE: 01/12/2011 Enclosures and Attachments Attachment 1; PT Burden Calculation (28 pages) Attachment 2; Potential Transformer Characteristic Ratio and Phase Angle Curve (1 page) Attachment 3; Drift Calculation (20 pages) Attachment 4; Manta MTS-1710 vendor information (3 pages) Attachment 5; HP 34401A Multimeter Accuracy Spec. (2 pages) Attachment 6; Calculation M-447 Rev. 1 used to establish maximum temperature in the 4KV switchgear room following a DBA. ( 1 page) Attachment 7; NIST analysis on human reaction time when using stop watch (4 pages) Attachment 8; Calculation 357A-DC, Revision 12, Study Case 009GS (1 page) Attachment 9; Calculation 357 A-DC, Revision 12, Summary (1 page) Attachment 10, FLUR Pickup Ratio Based on Historical Data (8 pages) Attachment 11; E-mail from ABB. Justification for Assumption 3.6 (1 page) Attachment 12; Applicability Determination (4 pages) File Name: 9000041128 (357S) Rev 1.doc 6/22/2011 I I CALCULATION NUMBER: 9000041128 REVISION:

1; LEGACY NUMBER: 357S-DC UNIT 1 PT Burden of 4.16 KV Bus F ELECT. REF DWG NO. TAG NO. LOC 437533 R40 VM HOI 437614 R33 27HFB4 TBD 437614 R33 27HFB3 TBD 437614 R33 & Basler Publication 9318700990 Page 1-13 27HFB2 SHFI2 437614 R33 27HFB1 SHFI2 437614 R33 27HFT1A TBD 437614 R33 27HFT1B TBD 437614 R33 27HFT1C TBD 437614 R33 27HFT2 TBD 437614 R33 & 445077 R3 YM418A CHF (VB4) 437614 R33 & A0520041 WLT(1) SHF12 437614 R33 & A0520041 WLT(1) SHFI2 437614 R33 & A0520041 WLT(1) SHF12 437614 R33 WLT CHF 437614 R33 & 437666 R30 WLT SHF7 437614 R33 & 437594 R30 WLT CNAS 437614 R33 & 437594 R30 WLT SHF8 437614 R33 & 437583 R24 WLT SHF9 437614 R33 & 437583 R24 WLT CB 437614 R33 & 437664 R17 WLT SHF13 437614 R33 & 437593 R31 37HF12 SHF12 437614 R33 & 437589 R16 WLT SHFI5 437614 R33 & 437589 R16 WLT CNSI 437614 R33 & 437621 R23 WLT SHF14 437614 R33 & 437593 R31 WLT CNCC 437614 R33 & 437593 R31 WLT SHF12 437614 R33 & 437595 R30 WLT SHFll 437614 R33 & 437595 R30 WLT CNV 437533 R40 WM CHF 437533 R40 VAR CHF 437595 R30 IHFI1ITD SHFII 437595 R30 2HF1l1TD SHF11 437595 R30 IHF11A1TD SHFll 437595 R30 2HF11A1TD SHFll 437594 R30 2HF8 SHF8 437594 R30 2HF8A SHF8 MFR WE ABB ABB Basler ABB ABB ABB ABB ABB Action Instruments GE GE GE WE GE WE GE GE WE WE Rochester GE WE GE WE GE GE WE WE WE AGASTAT AGASTAT AGASTAT AGASTAT AGASTAT AGASTAT ATTACHMENT "1" PT Burden Calculation VA PHASE MODEL A-B KA241 59N 59N 0.5 BEI-GPSI00E4NIHO 1 47H-412N0275-V 0.5 27N 0.5 27N 0.5 27N 0.5 59N AP6380 5 24EX/ET-6 3.66 24EXlET-6 24EX/ET-6 1.83 EZC 3.6 ET-16 EZC ET-16 ET-16 EZC ET-16 1200L ET-16 EZC ET-16 EZC ET-16 ET-16 EZC KP241 2.5 KP241 2.5 ETR-14I3A ETR-14I3B ETR-14I3A ETR-14I3D ETR-14I3D ETR-14I3D Page 79 of 152 VA VA W W W PHASE PHASE PHASE PHASE PHASE B-C A-C A-B B-C A-C Remarks 1.79 l.75 0.5 0.5 0.5 1 0.5 0.5 0.5 0.5 0.5 0.5 0.5 0.5 5 3.66 3.66 3.66 Load divided on 1.83 3.66 1.83 1.83 3.66 two tranSfOD11erS 3.6 5.33 5.33 3.6 3.6 5.33 5.33 5.33 5.33 3.6 3.6 5.33 5.33 0.5 0.5 5.33 5.33 3.6 3.6 5.33 5.33 3.6 3.6 5.33 5.33 5.33 5.33 3.6 3.6 2.5 2.5 2.5 2.5 2.5 2.5 6 6 6 6 6 6 6 6 6 6 6 6 II CALCULATION NUMBER: 9000041128 REVISION:

1; LEGACY NUMBER: 357S-0C UNIT 1 PT Burden of 4.16 KV Bus F ELECT. REF DWG NO. TAG NO. LOC 437583 R24 2HF9 SHF9 437583 R24 2HF9A SHF9 437589 R16 2HF15 SHF15 437600 R31 K608XF2 SPF 437600 R31 K609XFI SPF 437600 R31 4HFXFl SPF 437600 R31 4HFXF2 SPF 437593 R31 IHF12ffD SHF12 437593 R31 2HF12ffD SHF12 437593 R31 IHF12A/TD SHF12 437593 R31 2HF12A/TD SHF12 -----MFR AGASTAT AGASTAT AGASTAT P&B P&B P&B P&B AGASTAT AGASTAT AGASTAT AGASTAT ATTACHMENT "1" PT Burden Calculation VA PHASE MODEL A-B ETR-14I3D ETR-14I3D ETR-14I3B KHU-17A16-120 KHU-17AI6-120 KHU-17A16-120

KHU-17A16-120 ETR-14I3A ETR-14I3D ETR-14I3A ETR-14I3B I= 22.59 PF=Iw/IvA=

1.00 Page 80 of 152 VA VA W W W PHASE PHASE PHASE PHASE PHASE B-C A-C A-B B-C A-C Remarks 6 6 6 6 6 6 l.2 0.47 l.2 0.47 l.2 0.47 l.2 0.47 6 6 6 6 6 6 6 6 157.72 22.59 154.76 0.98 Based on the GE "Potential Transformer Characteristic Ratio and Phase Angle Curve" [Attachment 2], the ratio correction factor for the transformer with nominal 35: 1 ratio is For PF 1.00 & 22.59VA Burden: 0.9986 (A-B Phase) For PF 0.98 & 157.72VA Burden: 1.0052 (B-C Phase) Therefore the corrected transformer ratio is: A-B Phase: 0.9986 X 35 = 34.951 B-C Phase: 1.0052 X 35 = 35.182 I I' CALCULATION NUMBER: 9000041128 REVISION:

1; LEGACY NUMBER: 357S-DC UNIT 1 PT Burden of 4.16 KV Bus G ELECT. REF DWG NO. TAG NO. LOC 437533 R40 VM HOI 437614 R33 27HGB4 TSO 437614 R33 27HGB3 TSO 437614 R33 & Basler Publication 9318700990 Page 1-13 27HGB2 SHG12 437614 R33 27HGBI SHG12 437614 R33 27HGT1A TSO 437614 R33 27HGT1S TSO 437614 R33 27HGT1C TSO 437614 R33 27HGT2 TSO 437614 R33 & 445077 R3 YM419B CHG(VB5) 437614 R33 & A0520041 WLT (1) SHG12 437614 R33 & A0520041 WLT(l) SHG12 437614 R33 & A0520041 WLT(l) SHG12 437614 R33 WLT CHG 437614 R33 & 437666 R30 WLT SHG5 437614 R33 & 437664 R17 WLT SHG13 437614 R33 & 437621 R23 WLT SHG14 437614 R33 & 437593 R31 WLT SHG12 437614 R33 & 437593 R31 WLT CNCC 437614 R33 & 437593 R31 37HG12 SHG12 437614 R33 & 437591 R23 WLT SHG8 437614 R33 & 437591 R23 WLT CNR 437614 R33 & 437590 R19 WLT SHG7 437614 R33 & 437590 R19 WLT CNCS 437614 R33 & 437594 R30 WLT SHG6 437614 R33 & 437594 R30 WLT CNAS 437614 R33 & 4008756 R8 WLT SHG11 437614 R33 & 4008756 R8 WLT CNV 437614 R33 & 437595 R30 WLT SHG9 437614 R33 & 437595 R30 WLT CNV 437533 R40 WM CHG 437533 R40 VAR CHG 437595 R30 IHG9/TD SHG9 437595 R30 2HG9/TD SHG9 437595 R30 lHG9A1TD SHG9 MFR WE ASS ASS Basler ABB ASS ASS ASS ASS Action Instruments GE GE GE WE GE GE GE GE WE Rochester GE WE GE WE GE WE GE WE GE WE WE WE AGASTAT AGASTAT AGASTAT ATTACHMENT "1" PT Burden Calculation VA PHASE MODEL A-B KA241 59N 59N 0.5 BEI-GPS 100E4NIHO 1 47H-412N0275-V 0.5 27N 0.5 27N 0.5 27N 0.5 59N AP6380 5 24EXlET-6 3.66 24EXlET-6 24EXIET-6 1.83 EZC 3.6 ET-16 ET-16 ET-16 ET-16 EZC 1200L ET-16 EZC ET-16 EZC ET-16 EZC ET-16 EZC ET-16 EZC KP241 2.5 KP241 2.5 ETR-14I3A ETR-14I3B ETR-14I3A Page 81 of 152 VA VA W W W PHASE PHASE PHASE PHASE PHASE B-C A-C A-B B-C A-C Remarks l.79 l.75 0.5 0.5 0.5 1 0.5 0.5 0.5 0.5 0.5 0.5 0.5 0.5 5 3.66 I 3.66 3.66 Load divided on 1.83 3.66 1.83 1.83 3.66 two transfonners 3.6 5.33 5.33 5.33 5.33 5.33 5.33 5.33 5.33 3.6 3.6 0.5 0.5 5.33 5.33 3.6 3.6 5.33 5.33 3.6 3.6 5.33 5.33 3.6 3.6 5.33 5.33 3.6 3.6 5.33 5.33 3.6 3.6 2.5 2.5 2.5 2.5 2.5 2.5 6 6 6 6 6 6 II CALCULATION NUMBER: 9000041128 REVISION:

1; LEGACY NUMBER: 357S-0C Page 82 of 152 ATTACHMENT "1" PT Burden Calculation UNIT 1 PT Burden of 4.16 KV Bus G ---------------VA VA VA W W W ELECT. PI-IASE PHASE PHASE PHASE PI-IASE PHASE REF DWGNO. TAG NO. LOC MFR MODEL A-B B-C A-C A-B B-C A-C Remarks 437595 R30 2HG9A/TD SHG9 AGASTAT ETR-14I3D 6 6 437594 R30 2HG6 SHG6 AGASTAT ETR-14I3D 6 6 437594 R30 2HG6A SHG6 AGASTAT ETR-14I3D 6 6 437590 R19 & RPE E-07664 K645BX SHG7 P&B MDR-4103-1 18 4 437593 R31 IHG12/TD SHG12 AGASTAT ETR-14I3A 6 6 437593 R31 2HG12/TD SHG12 AGASTAT ETR-14I3D 6 6 437593 R31 IHG12A/TD SHG12 AGASTAT ETR-14I3A 6 6 437593 R31 2HG12A1TD SHG12 AGASTAT ETR-14I3B 6 6 437600 R31 K608XGl SPG P&B KHU-17A16-120 1.2 0.47 437600 R31 K609XG2 SPG P&B KHU-17A16-120 1.2 0.47 437600 R31 4HGXGI SPG P&B KHU-17AI6-120 1.2 0.47 437600 R31 4HGXG2 SPG P&B KHU-17A16-120 1.2 0.47 437591 R25 2HG8/TD SHG8 AGASTAT ETR-14I3B 6 6 437626 R32 2K617 RNSOB AGASTAT ETR-14I3D 6 6 L 22.59 178.65 22.59 161.69 PF=LwILVA=

1.00 0.91 Based on the GE "Potential Transformer Characteristic Ratio and Phase Angle Curve" [Attachment 2], the ratio correction factor for the transformer with nominal 35: 1 ratio is For PF 1.00 & 22.59VA Burden: 0.9986 (A-B Phase) For PF 0.91 & 178.65VA Burden: 1.006 (B-C Phase) Therefore the corrected transformer ratio is: A-B Phase: 0.9986 X 35 = 34.951 B-C Phase: 1.0082 X 35 = 35.287 ! I I 'CALCULATION NUMBER: 9000041128 REVISION:

1; LEGACY NUMBER: 357S-DC Page 83 of 152 ATTACHMENT "1" PT Burden Calculation UNITl PT Burden of 4.]6 KV Bus H VA VA VA W W W ELECT. PHASE PHASE PHASE PHASE PHASE PHASE REF DWG NO. TAG NO. LOC MFR MODEL A-B B-C A-C A-B B-C A-C Remarks 437533 R40 VM HOI WE KA241 1.79 1.75 I 437614 R33 27HHB4 TBD ABB 59N 0.5 0.5 I 437614 R33 27HHB3 TBD ABB 59N 0.5 0.5 437614 R33 & Basler Publication 9318700990 Page 1-13 27HHB2 SHH12 Basler BEI-GPSlOOE4NIHO 1 1 437614 R33 27HHBI SHH12 ABB 47H-412N0275-V 0.5 0.5 0.5 0.5 437614 R33 27HHT1A TBD ABB 27N 0.5 0.5 437614 R33 27HHT1B TBD ABB 27N 0.5 0.5 437614 R33 27HHT1C TBD ABB 27N 0.5 0.5 437614 R33 27HHT2 TBD ABB 59N 0.5 0.5 437614 R33 & 445077 R3 YM420D CHH (VB5) Action Instruments AP6380 5 5 437614 R33 & A0520041 WLT(l) SHH12 GE 24EXlET-6 3.66 3.66 437614 R33 & A0520041 WLT(l) SHH12 GE 24EXlET-6 3.66 3.66 Load divided on 437614 R33 & A0520041 WLT(l) SHH12 GE 24EXlET-6 1.83 1.83 3.66 1.83 1.83 3.66 two transformers 437614 R33 WLT CHH WE EZC 3.6 3.6 437614 R33 & 437666 R30 WLT SHH7 GE ET-16 5.33 5.33 437614 R33 & 437621 R23 WLT SHH14 GE ET-16 5.33 5.33 437614 R33 &437664 R17 WLT SHH13 GE ET-16 5.33 5.33 437614 R33 & 437593 R31 WLT SHH12 WE ET-16 5.33 5.33 437614 R33 & 437593 R31 WLT CNCC WE EZC 3.6 3.6 437614 R33 & 437593 R31 37HH12 SHH12 Rochester 1200L 0.5 0.5 437614 R33 & 437589 R16 WLT SHH15 GE ET-16 5.33 5.33 437614 R33 & 437589 R16 WLT CNSI WE EZC 3.6 3.6 437614 R33 & 437591 R23 WLT SHHll GE ET-16 5.33 5.33 437614 R33 & 437591 R23 WLT CNR WE EZC 3.6 3.6 437614 R33 & 437590 R19 WLT SHH9 GE ET-16 5.33 5.33 437614 R33 & 437590 R19 WLT CNCS WE EZC 3.6 3.6 437614 R33 & 437583 R19 WLT SHH8 GE ET-16 5.33 5.33 437614 R33 & 437583 R19 WLT CB WE EZC 3.6 3.6 437533 R40 WM CHH WE KP241 2.5 2.5 2.5 2.5 437533 R40 VAR CHH WE KP241 2.5 2.5 2.5 2.5 437593 R31 IHH12/TD SHH12 AGASTAT ETR-14I3A 6 6 437593 R31 2HH12/TD SHH12 AGASTAT ETR-14I3D 6 6 437593 R31 IHHI2A1TD SHH12 AGASTAT ETR-14I3A 6 6 437593 R31 2HHI2A1TD SHH12 AGASTAT ETR-14I3B 6 6 I I CALCULATION NUMBER: 9000041128 REVISION:

1; LEGACY NUMBER: 357S-DC UNIT 1 PT Burden of 4.16 KV Bus H ---ELECT. REFDWGNO.

TAG NO. LOC 437583 R24 2HH8 SHH8 437583 R24 2HH8A SHH8 437589 R16 2HH15 SHH15 437590 R19 & RPE E-07664 K645AX SHH9 437600 R31 K609XHI SPH 437600 R31 4HHXHI SPH 437591 R30 2HHIllTD SHHll 437627 R32 2K617 RNSOA MFR AGASTAT AGASTAT AGASTAT P&B P&B P&B AGASTAT AGASTAT ATTACHMENT "1" PT Burden Calculation VA PHASE MODEL A-B ETR-14I3D ETR-14I3D ETR-14I3B MDR-4103-1 KHU-17A16-120 KHU-17AI6-120 ETR-14I3B

ETR-14I3D I= 22.59 PF=Iw/IvA=

1.00 Page 84 of 152 VA VA W W W PHASE PHASE PHASE PHASE PHASE B-C A-C A-B B-C A-C Remarks 6 6 6 6 6 6 18 4 1.2 0.47 1.2 0.47 6 6 6 6 149.32 22.59 l33.82 0.90 Based on the GE "Potential Transformer Characteristic Ratio and Phase Angle Curve" [Attachment 2], the ratio correction factor for the transformer with nominal 35: 1 ratio is For PF 1.00 & 22.59VA Burden: 0.9986 (A-B Phase) For PF 0.90 & 149.32VA Burden: 1.0064 (B-C Phase) Therefore the corrected transformer ratio is: A-8 Phase: 0.9986 X 35 = 34.951 8-C Phase: 1.0064 X 35 = 35.224 I I II CALCULATION NUMBER: 9000041128 REVISION:

1; LEGACY NUMBER: 357S-DC UNIT 2 PT Burden of 4.16 KV Bus F -----ELECT. REF DWG NO. TAG NO. LOC 441229 R17 VM HOI 441340 R29 27HFB4 TBD 441340 R29 27HFB3 TSD 441340 R29 & Basler Publication 9318700990 Page 1-13 27HFB2 SHF12 441340 R29 27HFBI SHF12 441340 R29 27HFT1A TSD 441340 R29 27HFT1S TSD 441340 R29 27HFT1C TSD 441340 R29 27HFT2 TSD 441340 R29 & 445399 R7 YM418A CHF (VB4) 441340 R29 & A0520041 W LT(1) SHF12 441340 R29 & A0520041 WLT(1) SHF12 441340 R29 & A0520041 WLT(l) SHF12 441340 R29 & A0520041 WLT CHF 441340 R29 & 441315 R16 WLT SHF15 441340 R29 & 441315 R16 WLT CNSl 441340 R29 & 441345 R17 WLT SHF14 441340 R29 & 441349 R17 WLT SHF13 441340R29&441311 R23 WLT SHF12 441340 R29 & 441311 R23 & A0520041 WLT CNCC 441340 R29 & 441311 R23 37HF12 SHF12 441340 R29 & 496276 R7 WLT SHF7 441340 R29 & 441287 R26 & A0520041 WLT CNAS 441340 R29 & 441287 R26 WLT SHF8 441340 R29 & 441302 R21 WLT SHF9 441340 R29 & 441302 R21 & A0520041 WLT CB 441340 R29 & 441312 R26 WLT SHFll 441340 R29 & 441312 R26 WLT CNV 441229 R17 WM CHF 441229 R17 VAR CHF 441311 R23 IHF12ITD SHF12 MFR WE ASS ASS Basler ABB ASS ASS ASS ASS Action Instruments GE GE GE WE GE WE GE WE GE WE Rochester GE WE GE GE WE GE WE WE WE AGASTAT ATTACHMENT "1" PT Burden Calculation VA PHASE MODEL A-B KA241 59N 59N 0.5 BEI-GPSI00E4NIHO 1 47H-412N0275-V 0.5 27N 0.5 27N 0.5 27N 0.5 59N AP6380 5 24EXlET-6 3.66 24EXlET-6 24EXlET-6 1.83 EZC 3.6 ET-16 EZC ET-16 ET-16 ET-16 EZC 1200L ET-16 EZC ET-16 ET-16 EZC ET-16 EZC KP241 2.5 KP241 2.5 ETR-14I3A Page 85 of 152 VA VA W W W PHASE PHASE PHASE PHASE PHASE B-C A-C A-B B-C A-C Remarks 1.79 1.75 0.5 0.5 0.5 1 0.5 0.5 0.5 0.5 0.5 0.5 0.5 0.5 5 3.66 3.66 3.66 Load divided on 1.83 3.66 1.83 1.83 3.66 two transformers 3.6 5.33 5.33 3.6 3.6 5.33 5.33 5.33 3.6 5.33 5.33 3.6 3.6 0.5 0.5 5.33 5.33 3.6 3.6 5.33 5.33 5.33 5.33 3.6 3.6 5.33 5.33 3.6 3.6 2.5 2.5 2.5 2.5 2.5 2.5 6 6 I I CALCULATION NUMBER: 9000041128 REVISION:

1; LEGACY NUMBER: 357S-DC UNIT 2 PT Burden of 4.16 KV Bus F ELECT. REFDWGNO.

TAG NO. LOC 441311 R23 2HF12/TD SHF12 441311 R23 IHFI2A1TD SHF12 441311 R23 2HFI2A1TD SHF12 441312 R26 1HFli SHFll 441312 R26 1HFIIA SHFll 441312 R26 2HFIl SHFll 441312 R26 2HF11A SHFll 441302 R21 2HF9 SHF9 441302 R21 2HF9A SHF9 441287 R26 2HF8 SHF8 441287 R26 2HF8A SHF8 441315 R16 2HF15 SHF15 44l3l3 R26 K608XF2 SPF 441313 R26 K609XFl SPF 44l3l3 R26 4HFXFl SPF 441313 R26 4HFXF2 SPF --MFR AGASTAT AGASTAT AGASTAT AGASTAT AGASTAT AGASTAT AGASTAT AGASTAT AGASTAT AGASTAT AGASTAT AGASTAT P&B P&B P&B P&B -ATTACHMENT "1" PT Burden Calculation VA PHASE MODEL A-B ETR-14I3D ETR-14I3A ETR-14I3B ETR-14I3A ETR-14I3A ETR-14I3B ETR-14I3D ETR-14I3D ETR-14I3D ETR-14I3D ETR-14I3D ETR-14I3B KHU17AI6-120 KHU17A16-120

KHU17A16-120 KHU 17 A 16-120 L 22.59 PF=LwILVA 1.00 Page 86 of 152 VA VA W W W PI-IASE PHASE PHASE PHASE PHASE B-C A-C A-B B-C A-C Remarks 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 1.2 0.47 1.2 0.47 1.2 0.47 1.2 0.47 157.72 22.59 154.76 0.98 Based on the GE "Potential Transformer Characteristic Ratio and Phase Angle Curve" [Attachment 2], the ratio correction factor for the transformer with nominal 35: 1 ratio is For PF 1.00 & 22.59VA Burden: 0.9986 (A-B Phase) For PF 0.98 & 157.72VA Burden: 1.0050 (B-C Phase) Therefore the corrected transformer ratio is: A-8 Phase: 0.9986 X 35 = 34.951 8-C Phase: 1.0052 X 35 = 35.182 II CALCULATION NUMBER: 9000041128 REVISION:

1; LEGACY NUMBER: 357S-DC UNIT 2 PT Burden of 4.16 KV Bus G ELECT. REF DWG NO. TAG NO. LOC 441230 R26 VM HOI 441340 R29 27HGB4 TSD 441340 R29 27HGB3 TSD 441340 R29 & Basler Publication 9318700990 Page 1-13 27HGB2 SHG12 441340 R29 27HGB1 SHG12 441340 R29 27HGT1A TSD 441340 R29 27HGT1S TSD 441340 R29 27HGT1C TSD 441340 R29 27HGT2 TSD 441340 R29 & 445399 R7 YM419B CHG(VB5) 441340 R29 & A0520041 WLT(1) SHG12 441340 R29 & A0520041 WLT(1) SHG12 441340 R29 & A0520041 WLT(l) SHG12 441340 R29 & A0520041 WLT CHG 441340 R29 & 4008751 R8 WLT SHG11 441340 R29 & 4008751 R8 WLT CNV 441340 R29 & 441345 R17 WLT SHG14 441340 R29 & 441349 R17 WLT SHG13 441340 R29 & 441311 R23 WLT SHG12 441340 R29 & 441311 R23 & A0520041 WLT CNCC 441340 R29 & 441311 R23 37HG12 SHG12 441340 R29 & 441309 R22 WLT SHG8 441340 R29 & 441309 R22 & A0520041 WLT CNR 441340 R29 & 441307 R16 WLT SHG7 441340 R29 & 441307 R16 & A0520041 WLT CNCS 441340 R29 & 441287 R26 WLT SHG6 441340 R29 & 441287 R26 WLT CNAS 441340 R29 & 441312 R26 WLT SHG9 441340 R29 & 441312 R26 WLT CNV 441340 R29 & 441356 R13 WLT SHG5 441230 R26 WM CHG MFR WE ASS ASS Basler ABB ASS ASS ASS ASS Action Instruments GE GE GE WE GE WE GE GE GE WE Rochester GE WE GE WE GE WE GE WE GE WE ATTACHMENT "1" PT Burden Calculation VA PHASE MODEL A-B KA241 59N 59N 0.5 BE1-GPS100E4N1HO 1 412N0275-V 0.5 27N 0.5 27N 0.5 27N 0.5 59N AP6380 5 24EXlET-6 3.66 24EXlET-6 24EXlET-6 1.83 EZC 3.6 ET-16 EZC ET-16 ET-16 ET-16 EZC 1200L ET-16 EZC ET-16 EZC ET-16 EZC ET-16 EZC ET-16 KP241 2.5 Page 87 of 152 VA VA W W W PHASE PHASE PHASE PHASE PHASE B-C A-C A-B B-C A-C Remarks 1.79 1.75 0.5 0.5 0.5 1 0.5 0.5 0.5 0.5 0.5 0.5 0.5 0.5 5 3.66 3.66 3.66 Load divided on 1.83 3.66 1.83 1.83 3.66 two transformers 3.6 5.33 5.33 3.6 3.6 5.33 5.33 5.33 5.33 5.33 5.33 3.6 3.6 0.5 0.5 5.33 5.33 3.6 3.6 5.33 5.33 3.6 3.6 5.33 5.33 3.6 3.6 5.33 5.33 3.6 3.6 5.33 5.33 2.5 2.5 2.5 II CALCULATION NUMBER: 9000041128 REVISION:

1; LEGACY NUMBER: 357S-DC UNIT 2 PT Burden of 4.16 KV Bus G ELECT. REF DWG NO. TAG NO. LOC 441230 R26 VAR CHG 441311 R23 IHG12/TD SHG12 441311 R23 2HGI2/TD SHGI2 441311 R23 IHG12A/TD SHG12 441311 R23 2HGI2A/TD SHG12 441287 R26 2HG6/TD SHG6 441287 R26 2HG6A1TD SHG6 441312 R26 IHG9/TD SHG9 441312 R26 lHG9A/TD SHG9 441312 R26 2HG9/TD SHG9 441312 R26 2HG9A1TD SHG9 441307 R16 & RPE E-07664 K645BX SHG7 441309 R22 2HG8/TD SHG8 441313 R26 K609XGI SPG 441313 R26 K608XGl SPG 441313 R26 4HGXGl SPG 441313 R26 4HGXG2 SPG 441353 R29 2K617 RNSOB MFR WE AGASTAT AGASTAT AGASTAT AGASTAT AGASTAT AGASTAT AGASTAT AGASTAT AGASTAT AGASTAT P&B AGASTAT P&B P&B P&B P&B AGASTAT ATTACHMENT "1" PT Burden Calculation VA PHASE MODEL A-B KP241 2.5 ETR-14I3A ETR-14I3D ETR-14I3A ETR-14I3B ETR-14I3D ETR-14I3D ETR-14I3A ETR-14I3A ETR-14I3B ETR-14I3D MDR-41 03-1 ETR-14I3B KHU-17AI6-120 KHU-17A16-120 KHU-17AI6-120 KHU-17AI6-120 ETR-14I3D I= 22.59 PF =LwILVA = 1.00 Page 88 of 152 VA VA W W W PHASE PHASE PHASE PHASE PHASE B-C A-C A-B B-C A-C Remarks 2.5 2.5 2.5 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 18 4 6 6 1.2 0.47 1.2 0.47 1.2 0.47 1.2 0.47 6 6 178.65 22.59 161.69 0.91 Based on the GE "Potential Transformer Characteristic Ratio and Phase Angle Curve" [Attachment 2], the ratio correction factor for the transformer with nominal 35: 1 ratio is For PF 1.00 & 22.59VA Burden: 0.9986 (A-B Phase) For PF 0.91 & 178.65VA Burden: 1.0082 (B-C Phase) Therefore the corrected transformer ratio is: A-8 Phase: 0.9986 X 35 = 34.951 B-C Phase: 1.0082 X 35 = 35.287 II CALCULATION NUMBER: 9000041128 REVISION:

1; LEGACY NUMBER: 357S-DC Page 89 of 152 UNIT 2 PT Burden of 4.16 KV Bus H ---------ELECT. REF DWGNO. TAG NO. LOC 441230 R26 VM HOI 441340 R29 27HHB4 TBD 441340 R29 27HHB3 TBD 441340 R29 & Basler Publication 9318700990 Page 1-13 27HHB2 SHH12 441340 R29 27HHBI SHH12 441340 R29 27HHT1A TBD 441340 R29 27HHT1B TBD 441340 R29 27HHT1C TBD 441340 R29 27HHT2 TBD 441340 R29 & 445399 R7 YM420D CHH(VB5) 441340 R29 & A0520041 W LT(1) SHH12 441340 R29 & A0520041 W LT (1) SHH12 441340 R29 & A0520041 WLT(1) SHH12 441340 R29 & A0520041 WLT CHH 441340 R29 & 441315 R16 WLT SHHl5 441340 R29 & 441315 R16 WLT CNSl 441340 R29 & 441345 R17 WLT SHH14 441340 R29 & 441349 R17 WLT SHH13 441340 R29 & 441311 R23 WLT SHH12 441340 R29 & 441311 R23 & A0520041 WLT CNCC 441340 R29 & 441311 R23 37HH12 SHH12 441340 R29 & 441309 R22 WLT SHH11 441340 R29 & 441309 R22 & A0520041 WLT CNR 441340 R29 & 441307 R16 WLT SHH9 441340 R29 & 441307 R16 & A0520041 WLT CNCS 441340 R29 & 441302 R21 WLT SHH8 441340 R29 & 441302 R21 & A0520041 WLT CB 441340 R29 & 441356 R13 WLT SHH7 441230 R26 WM CHH 441230 R26 VAR CHH 441311 R23 lHH12/TD SHH12 441311 R23 2HHl2/TD SHH12 4413]] R23 lHH12A1TD SHH12 441311 R23 2HHI2A1TD SHH12 MFR WE ABB ABB Basler ABB ABB ABB ABB ABB Action Instruments GE GE GE WE GE WE GE GE GE WE Rochester GE WE GE WE GE WE GE WE WE AGASTAT AGASTAT AGASTAT AGASTAT ATTACHMENT "1" PT Burden Calculation VA PHASE MODEL A-B KA241 59N 59N 0.5 BEI-GPSI00E4NIHO 1 412N0275-V 0.5 27N 0.5 27N 0.5 27N 0.5 59N AP6380 5 24EXlET-6 3.66 24EXlET-6 24EXlET-6 1.83 EZC 3.6 ET-16 EZC ET-16 ET-16 ET-16 EZC 1200L ET-16 EZC ET-16 EZC ET-16 EZC ET-16 KP241 2.5 KP241 2.5 ETR-14I3A ETR-14I3D ETR-14I3A ETR-14I3B VA VA PHASE PHASE B-C A-C 1.79 0.5 0.5 0.5 3.66 1.83 3.66 5.33 3.6 5.33 5.33 5.33 3.6 0.5 5.33 3.6 5.33 3.6 5.33 3.6 5.33 2.5 2.5 6 6 6 6 W W PHASE PHASE WPHASE A-B B-C A-C Remarl<s 1.75 0.5 0.5 1 0.5 0.5 0.5 0.5 0.5 0.5 5 3.66 3.66 Load divided on 1.83 1.83 3.66 two transformers 3.6 5.33 3.6 5.33 5.33 5.33 3.6 0.5 5.33 3.6 5.33 3.6 5.33 3.6 5.33 2.5 2.5 2.5 2.5 6 6 6 6 I I CALCULATION NUMBER: 9000041128 REVISION:

1; LEGACY NUMBER: 357S-0C UNIT 2 PT Burden of 4.16 KV Bus H ELECT. REF DWG NO. TAG NO. LOC 441302 R21 2HH8 SHH8 441302 R21 2HH8A SHH8 441315 R16 2HH15 SHH15 441307 R16 & RPE E-07664 K645AX SHH9 441309 R22 2HHII1TD SHHll 441313 R26 K609XHI SPH 441313 R26 4HHXHI SPH 441354 R30 2K617 RNSOA .............

MFR AGASTAT AGASTAT AGASTAT P&B AGASTAT P&B P&B AGASTAT ATTACHMENT "1" PT Burden Calculation VA PHASE MODEL A-B ETR-14I3D ETR-14I3D ETR-14I3B MDR-4103-1 ETR-14I3B KHU-17AI6-120 KHU-17AI6-120 ETR-14I3D I= 22.59 PF =L:W/L:vA=

1.00 Page 90 of 152 VA VA W W PHASE PHASE PHASE PHASE WPHASE B-C A-C A-B B-C A-C Remarks 6 6 6 6 6 6 18 4 6 6 1.2 0.47 1.2 0.47 6 6 149.32 22.59 133.82 0.90 Based on the GE "Potential Transformer Characteristic Ratio and Phase Angle Curve" [Attachment 2], the ratio correction factor for the transformer with nominal 35: 1 ratio is For PF 1.00 & 22.59VA Burden: 0.9986 (A-B Phase) For PF 0.90 & 149.32VA Burden: 1.0064 (B-C Phase) Therefore the corrected transformer ratio is: A-8 Phase: 0.9986 X 35 = 34.951 8-C Phase: 1.0064 X 35 = 35.224 I I CALCULATION NUMBER: 9000041128 REVISION:

1; LEGACY NUMBER: 357S-DC Page 91 of 152 Summary Unit 1 Device Phase 1-27HFB2 A-B 1-27HGB2 A-B 1-27HHB2 A-B 1-27HFTI A-B 1-27HGTI A-B 1-27HHTI A-B 1-27HFT2 B-C 1-27HGT2 B-C 1-27HHT2 B-C 1-27HFB3 A-B 1-27HGB3 A-B 1-27HHB3 A-B 1-27HFB4 B-C 1-27HGB4 B-C 1-27HHB4 B-C ATTACHMENT "1" PT Burden Calculation PT Ratio Device 34.951 2-27HFB2 34.951 2-27HGB2 34.951 2-27HHB2 34.951 2-27HFTI 34.951 2-27HGTI 34.951 2-27HHTI 35.182 2-27HFT2 35.287 2-27HGT2 35.224 2-27HHT2 34.951 2-27HFB3 34.951 2-27HGB3 34.951 2-27HHB3 35.182 2-27HFB4 35.287 2-27HGB4 35.224 2-27HHB4 Unit2 Phase PT Ratio A-B 34.951 A-B 34.951 A-B 34.951 A-B 34.951 A-B 34.951 A-B 34.951 B-C 35.182 B-C 35.287 B-C 35.224 A-B 34.951 A-B 34.951 A-B 34.951 B-C 35.182 B-C 35.287 B-C 35.224 I CALCULATION NUMBER: 9000041128 REVISION:

1; LEGACY NUMBER: 357S-DC ATTACHMENT "1" PT Burden Calculation Exhibit (1): Westinghouse Voltmeter KA241 Burden Page 4 \NS£' nNdlH(}UI-, Ac Lass Data. 60 Hem -:,Cifcll'lorScate*K-24'1, K.231. <<-211 '. '".:Ac-lnsfnItne"f,s 1.0$$ .Data, eo CyGIH. Circular Sc&le .1(-241. K-231 ;-K..z61 -.. Burden,on ,Current Tfl?Sformerc at 6 Afnp$ in51tdmoot

!fVPll .

.4 Ro;l,tMlr;e:

.'

'Volt*

  • pllWJeJ' *and Roling 'Ohm.' .: . Ohms. Henrie!! AmPllItOlli Factor 6 AmPl: .* 036 Splrut Vane leA '.026 .000066 ,9 .'12 ftDpulslon-AttlliClloli@

KA .oUi .012 .000024 . .315 ',80 fleetlner KC . .Q02 .0016 .oS .DD .Wattmeter'll and Vamuter, KP} .Q8 .OHi .0002 2.0 20 (Per 6 Mp$ KV Powcr.

Metera. ,Kt :174 .14 -.:4,35 .82 SAmps KJ .045 .045 U2 ",0 Burdefl on Voltage Tl1In$forrncl'$

Ilt 120 Volts lmlfument Type ImDodance:

Rallimnr:o:

InduClatI(ro!

VoU* Powttr end Rating Ot1l11$

  • Henr-too f,e,Qf VolunetOfS.

()'160 Volts: 120Volt1J Sptral Vane 'KA 8&40 8420 5.1 1.79 .98 ftepull.iQn-AttftlcUoo m . teA ,7530 7600 1.92 .99G Rectifior KC 150.000 150,000 .* 096 1.0 WaHmlli'Ou.

tlnt! VatmeW$, 1tO Volts; Single Phase {KP\ 9.000 9,000 :2.15 UI Polyphase tV1 18,000 '18,000 1.26 1.0 Phali" Stllftot PS*2 } 1.4 .36 MV*83Z 'Frcquoncy

\120 VoU!i KR3 . 4,000 4.000 :U 1.0 , Power Faetor Mel13fs, 120 Volts: Smgla PhaGe KI 4.5 .46 f(J .12,000 12;000 1.2 1.0 Polyphase KI 2.2 1.0 f(J 14.000 14..000 1.2 1.0 Synehms.eoPfi.

12() IVoltl;: 4.5 .45 RUnning tel ItlCOM!rig 4.6 .80 @All Ht43hock t\ipac.nd ccmrmln:ial rn:tflufactunJd priM kl1977 ore Watu .65 .30 .04 .4 1.12 1.12 W1U1a, 1.76 1.92 .(lOG 2.5 1.25 .6 3.6 2.0 1.2 2.2 1.2 2.0 3.7 Page 92 of 152 .:l &/7 t..c :iJ 17¢.13 -.1J4,IJ.e.v, ) "rTHeft. $.,3 /'=>>4-* ..2-er OF ..:&:r 2..5. 2.$ Iteactm V04t* A,rnper. .625 .G2S z.o RoacU\lu Volt* , AmpefBII ;40 +--1.3 *M 4.1 UJ CALCULATION NUMBER: 9000041128 REVISION:

1; LEGACY NUMBER: 357S-DC ATTACHMENT "1" PT Burden Calculation Exhibit (2) ABB 27N & 59N Undervoltage Relay Burden Descriptive Bulletin 41-233S Page 2 Specifications Input Circuit Rating: Burden: Frequency:

Output Circuit: Control Power: Temperature:

Tolerances: (Without harmonic filter module, after 10 minute warm*up.)

Tolerances: (With harmonic filter module) Reset Time: Seismic Capability:

Transient Immunity:

Dielectric:

Weight: Type 27N 150 Vac Maximum Continuous Type 59N 160 Vac Maximum Continuous Less than 0.5 VA at 120 Vac Wt60 Hz. Each contact at 125 Vdc: 30A Tripping Duty SA Continuous 1 A Break. Resistive O.3A Break, Inductive.

Rated at 48/125, 250 Vdc at 0.05 ampere maximum. ANSI range -2O"C to +5S'C Must operate -30'C to + 10*C Pickup and dropout settings with respect to printed dial markings (factory calibration)

.". :t2%. Pickup and dropout settings, repeatability at constant temperature and constant control voltage", :0.1%, {See Note} Pickup and dropout settings.

repeatability over DC control power range of 100*140 volts '" +/-O.1%. (See Nole) Piclrup and dropout settings.

repeatability over temperature range: (See Note) -20*C to +55°C :to.4% -20'Cto t70"C :!:0.7% O'C 10 + 40'C +/- 0.2% Note: The three tolerances shown should be considered independent and may be cumulative.

Tolerances assume pure sine wave Input signal. Time Delay Instantaneous model: 3 cycles or less operating time. Definite Time models (see appropriate curve). :t 10% or +/- 20 milliseconds, whichever is greater. An ratings are the same except: Pickup and dropout settings, repeatability over temperature range: . O"Cto +55"C :to.75% + 10"C to +4O"C :to.4O"/c. 20"C to + 70"C :t 1.50% Less than 2 cycles (Type 21N). less than 3 cycles (Type S9N). (The relay resets when the inpul voltage goes above the pickup setting -27N. below the dropout setting -59N.) More than 6g ZPA either AXIS biaxial broadband multifrequency vibration without damage or malfunction ANSIIlEEE C37.98. More than 2S00V. lMHz bursts at 400 Hz repetition rate. continuous (ANSI C37.90.1 SWC): Fast transient test. EMI test 2000 Vac RMS 60 seconds all circuits to ground. Unboxed* 3.7Ibs. (1.1 kg) Boxed -4.3 Ibs. (2.0 kg) Volume* 0.26 cubic feet A How To Specify Voltage Relay shall be Asea Brown Bover! Type 21N. Type 59N or approved equal, out case, capable 01 withstanding up to 6g ZPA seismic stress without damage or malfunction.

at minimum voltage and time settings.

A netic operation indicator shall be provided which retains position on loss of control power. Built-in means shall be provided to allow ational tests without additional equipment.

IUI--+-+--+--+!-=-+_-I

t-t-+-+-+=-t 0
.2 4A AG e-e to \.l llita\tltLUOf fMS&tTtlll; fWE
  • 1 $;oJtdII "'I--+-+-+-+.:...t--l II "-

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= 'II

cu ** .$ I. It _tTl"-U OF fJ1JUlIIiG TVI'£ 2>11

/!RAY Note: TI'Tle delays assoclaled With the time taps fOf the Type 59N Overvortage Relay are identical to those of the Type 21N Undervoltage Relay. except lhe delay occurs on pickup: i.e .* when voltage to above Ule pickup lap setting. How To Order For a complete listing of available versions of single and three phase voltage relays see TO 41'()25. Models are available for 48 to 250 Vdc control power, and 120 Vac potential transformers.

For other control voltages contact the nearest ABB Representative.

To place an order, or for further information, contact the nearest ABB Representative.

Further Information USI Prices: PL 41-020 Technical Data: TO 41..Q25 Instruction Book: IB 7.4.1.7-1 Other Protective Relays: Application Selector Guide. TO 4H)16 Page 93 of 152 I September 1995 I CALCULATION NUMBER: 9000041128 REVISION:

1; LEGACY NUMBER: 357S-DC ATTACHMENT "1" PT Burden Calculation Exhibit (3): Basler BE1-GPS100 Undervoltage Relay Burden GENERAL SP E CIFICATIONS AC Current Inputs 5 Ampere or Continuou s Rating: One Second Ra.ting: Sa turati o n Limit: Burden: 1 Amoere CT ContinuoLls Rating: One Second Rating: 20A 400 A F o r other ClIIrent levels , u se the f O lrll lila: 1 = (I{.,,,!o'i where t = time in seconds, K=1 60,OOO(A11 Case styles) 150 A <.10 milliol1ms 4A 80A F o r other CUlrent level.!), use the f O lm u la: I = where t = time in seconds j Saturation Limit: K = 1 60,000 (81 case), K = 90,000 (Hi ca.se) 30A Burden: Phase A C Voltage Inputs Co ntinuous Rating: One Second Ra.tinq: Burden: 93187009'9(}

Rev H 10 milliohms or Less at 1A 300 V, Lin!;! to Line 600 V, Line tl) Neutral <1 VA @ 300Vac BE1 B GPSHW Generallnfonnation 1*13 Page 94 of 152 I CALCULATION NUMBER: 9000041128 REVISION:

1; LEGACY NUMBER: 357S-DC Page 95 of 152 1 ATTACHMENT "1" PT Burden Calculation Exhibit (4): ABB 47H Undervoltage Relay Burden IB 7.4.1.7-2 PageS SPECIFICATION S UJ pu( Cin;*\Iit: Three-Phase Undervoltage Relays Rating: l20v models: 160WI C, coutinllous

.. 50 Of 60 J [z. 208v models: 270vac, continuous, 50 or 60 ) f z. Burdell: 120v modc[s: Iess Ullln 1 VA. 1.0 I'F (11 12 0 vo lts. 208v models: less than 1 VA. 1.0 r t F nt 208. volts. Tnps: aVl1 ila blc models include: Types 47 , 47D , 47H: Types 47D, 47H: Pickup 90,) 00, 110, J 20 vac. f)i c.k'up 155, 175. 190,208 vnc. Dropo u t 70, 80, 90, 98% ofpick'llp.

Pkkup 90, 100, 110, 120 vue*. DrotJOut 30, 40, 50, (iO% of pick\lp. Vendor Catalog Information

-. t" 0, o U 15 14 1:1 o 0 0 0 I"". " 423 h .. in Typ.47 .. tUtt ... 412H , ... Figure 3a: Typical Control connectione

-voltage controllod Overcl,lr-,.ent Relay (SIV) type fil Catalog Sertea 423 (3 phaoe) and Type 47H Catalog Sories "'2N I I I _ .... i -r.

.. S. Phase B Based on Drawing 441340 Half of the 1 VA burden is on phase A and the other half on phase C I CALCULATION NUMBER: 9000041128 REVISION:

1; LEGACY NUMBER: 357S-0C ATTACHMENT "1" PT Burden Calculation Exhibit (5): GE 24EX I ET-6 Lamp: u 1l,..:I . 'e 2 1, 1979 J -"0 J. 1919 @it ..: H';A 1;ON-ET ... 5, ET-6 'me E'i:'S metal base indicating

_ (lJr atld U am:h under r.m e number. ler Olnother c-atruog number for 1-. -indicating Lamps' Types ET .. 5, ET .. 6 = 2. &nes resistor prevents the pollsi o .bitity of a short circuit from a broken .lamp filament thus eliminating the need . for special fuses and assuring long Jamp life. , and. 2*L,ch*th1r;l, panels. Also

3. Low-wattage consumption results f'or-tbin*pane1applications; up to U-in economy and cool operation.

is the*mo1tled-base Type ET-61amp.

combinations

  • E tete-Flg. 1. . ad' 'bI in phone lamp, .Tl'"pe 1'2, tUde base lamp !d be applie' WLl.e1" e go VlSJ e
  • rated 24 vo1ts 0.032-0.038. ampere. The tion, long lamp life, and

...... .....".,

are deairable.

They can be -special Code 24X lamp is used in tho -. for indication

o. in and Code 24EX lamp is ET-6. lPbOIQ 11021).439\

fyPlt ET-S lndicClli119 IlImp i'nollnl.d on (ft$ulgli"S 1>1:1 1'11<'

  • Page 96 of 152 ( I, b i natlon

-,--5 .. .are -designed

circuit-br eaker po9.ition.

_ . mum -vismUity.

See Table 1 for avail-VI GE ET -6 r a ted 1 1 25VD C .i s i n . .: , able colors.

Each unit compact and simple in 6. Terminals are readily and ,truC--..lOth Reauire" only (lne hole for have facilities fot' soldered of clampro W -connections.

C1NG INFORMATION-ET

.. S AND ET0.6 IND1CATING LAMPS (Pllolo 20AC C I rcu i t TyplIE:!'..-614'

/ (P e r 357 K-DC Re v. 3) cUcl'lHng lamp nu,u l)l' L-__________________ ORDERING Cat:' I Powet 5yuemJ MonogelJ'l"nt*NR210(0)

Group 1'1<>. * <fr.." V.'m,. \ c ..

  • :iSo,

... ; ..

.. .. I u .. r .. I u ** roo Not MQr .. cfhtl"" Itll1aJor ftJ'Jnl mum I" Oh.II \lib I.. EC cleo ote cmp U I l' o :, , 110 I 140 3300 .'. I 1 280 7200 .... t 75-0 20,000 I 125 I , SCQ 13,C-oO A:'! 0 ____ J7.000 wop Cclo, Cap, l:.

Yc t: altd Res1'h,tl P a nels " .. 1>01. I'o"els" I d ot One Bnlhuncy pero e .,

6105101) ()3':-G21-!-6105100 044-02l+ G.t-1+ 045 61051'00 OS 023 09+-GVo!-049t!-6105700 &105700 010-10 (;28+ G50':-610.$100 0 29 G51 'i' ._" .6tO S70t). 030 (is;!

Each 11.30 8.30 8.30 11.30 0.30 tt.40

>>,,1 P,j ... , Ea .. " n 7.55 7.SS 7.$3 7.!O3 7,55 10.1.5 10.ts ---N Ho .... Cl".:If" a"do;; ('tt.,/I*> I"ue;r Amher. Gfe"l\r RerIr GE Type ET-6 indicating lamps are rated 125VDC for use in 120VAC circuits ET-6 Rating = 125VDC, ET-6 Resistance

= 33000 Bulb rating = 24VDC, Bulb Maximum current = 0.038A, Bulb maximum wattage: 24 X 0.038 = 0.912W Bulb resistance

= 0.912 / (0.038)2 = 632 0 Total socket & bulb resistance

= 3300 + 632 = 3932 0 Current at 120VAC = (120V)/(3932

0) = 0.0305A Burden = (0.305)2 X 3932 n = 3.66W tel'trea p 257.1.57291'1 2S7AS72?1'2 2S7J..5729l'3 257.1.57191'4 2571o.5729PS 257AS72v?7 25 7 A!i729 P9 I ! r ! 1 I CALCULATION NUMBER: 9000041128 REVISION:

1; LEGACY NUMBER: 357S-DC Page 97 of 152 ATTACHMENT "1" PT Burden Calculation Exhibit (6): Westinghouse Lamp Type EZC Burden: DB 34 ... 350 Page 2

  • Indicating Lamps EZC Minalite The Type EZC Minalite a compaCt indi* cating lamp. de&tgnf!d for genefallndicatlng Of sT9fjaiing p"UrposllS on switohboards, COntrol dellik,s, etc. A complete lamp con*

of a standard JC&istof, receptacle.

e fow drain telephone type slide base bUlb t lar spacers. octagon mounting nut. lens and termlnal hardW()f(l.

The resistor. ceptacle.-bl.1lb and lens are $hipped bled, The other parts are enclosed tn an wlope. TheS>e two items are incorporated into ill Singte package which is identified bV a single style numbel fot tho required lamp. The EZC indIcating lamp is suitable for mounting on panels. up to and including

% inch thickness.

and ere of a de$ign that permits qutck Bnd easy installation.

They ere inserted from the rear of the panel, after una screwing lens from resistoNeceptacle as*

through annular ,as 'Jirad for panel thickness.

Ttghterllng t!le , .. tagon nut from the front of the P?flel . "mollots the assembly.

The one-pIece molded lens is then screwed 00, enclosing the lamp receptacle and the front mounting nut. Wiring connections Bre easily made at tho rear end of the assembly.

The round receptacle and lens affords curate alignment on the panel. The rear mimd, located on 100 axial tie rod" can be rotated 360 degrees and bent up 90 degrees to positions best suited to wiring require-ments. . Lamp Data riles Gil Vi A oltago c-Dc 2S flO 70 115 125 20S 230 200 3SO 480 Style Numbers BniJ LtlJI$ Co!or Red Gmra 4490181610 449018702-0 449D187G11 4490187G21 449D187G12 449D181G22 449D187G23 449D187G14 4490187G24 449D187615 449D187625 4490187016 44901810%6 44tD187617 1449D187621 449D187G18 44$D187G28 449D187619 4480181G29 J.. Sec.. 9 tC /!J'J.,c.

':JI1 17 ¥ JJCj/l-QAl. Dlmemdons in Inches II* T ** .o6,.,. MI *. S ...... Omit I for .19 Ponel. Omll 2 for .25 Ponel.

8!3 -M-;!)j! " a.S" 'nl:OlTling Wlte Tetm. Connected In tilts Area H t .641DrlU N(JtC$: 1. 'fWD .062 mountinQ tpacers fumishGd for .125 THK panel mount* Ing. Omilfor .25 THK paMeI. 2.. Mounting nutia Underneath tllM(J'Iable lenG and ammblcdaoainst front of j>>nlll. . 3. Rearterminala tlte factory t&t sp.t/cl!d 90* apart but can be IIdjustld lD:MJlttaklng c!amncobflMlicn Icrmlnol:t.

  • . TotalWsU!!

Wl1l1e BluB Ambflr Ice ol,age 449D1i1G30 4490187G40 449D187G50 449D187G60 0.9 4490187031 44I1D187G41 4490187(;61 449D181G61 1 ** 449D187Gi2 44&01870,42 449D187062 44901871362 2.3 4 4490187G33 44&1>1816"43 4490187G53 449D187GIi3 3.5 44I1D187034 449D187G44 4490187G64 4.0 449D187035 449D187G45 449D181G55 449D187665 6.G .. 449D187G3B 4490187G46 449D187G56 4490187G68

.13 4490181037 449D187G41 449D181G61 449D187(367 7.Jl 44SD181G38 449D187048 44901&7668 448D187G68

'11.8. 44901871339 449D187649 449D187669

_4490197G69 16.3 I CALCULATION NUMBER: 9000041128 REVISION:

1; LEGACY NUMBER: 357S-0C ATTACHMENT "1" PT Burden Calculation Exhibit (7): GE ET-16 Lamp Burden 06/12.'1990 13:51 FROM GE EMERYVILLE 415 4280165 TO 9973ge61 P.02/l2l2 . .". -CONTROL SWITCHES AND ACQSSORIES Indicating' Lamps1f . "Types IT.16 and EY.l1 $.200, Sa225;u..soo, $.635 I .c./# .. t;. r113'S71\-.D£;I<4';/.3 7165 Page' Oct. 15. 19$4 A'TrAc.rl._ _ -:

  • A:s J 6-of 17." t:in::lI\tVolloO,
  • ftc;. eel<< Olaf emfito. :t CII9 I'Itt Ma:>>. . ) Ohm, TIIIfIi TG9 4tJ,: 44 $6 gmmIW " iI so I hi! 110 140 ! = } te1$ i: i ao CHi? 1 130 .c 4. itl8 = :! 19! :60 0127181 $ ;; , 0 *ET-l1-tNDICATING lAMP = I hIb 'cr thf.. PwI 01 I'M tw. Ctc!. N4. , Bii ' I 4.-i '2 ) a ItA 'ft .. 1m: I :! 00 ;; ; I n. for q*t1tleJ or or JnOt'O to .by combinaticc or ET-16ecS 11 'l =Cler tht Com1'¢lltftt PtoIBID of' La'boatoriC$, Inc. DIMENSIONS-Subjeet to Should "ot be UStd to: const.nlCticl1 without approval:

.. fleMt **tfIH ,A

  • C; V*"

In ...

'tttU 1/1 . tv.

Oh/; ... ..

t::!CllfliwiliGit ORDERING TA1UE 2-=-Cotot CElp "I/' + HOW TO ORDER. . <>nktbs Qt. No. 8Dd coJorcap.

  • ../Je t.J& Hrs DJt.lJ£Nl r;..o wD,&,H 1-6/f. L,..5l>:J/

I *PfUClHG !ld'er to Section 7213. Page 98 of 152 I CALCULATION NUMBER: 9000041128 REVISION:

1; LEGACY NUMBER: 357S-0C ATTACHMENT "1" PT Burden Calculation AUG-29-98 FROM,OUKE ENG SAN RAMON l.Iql Vac{H) tlttml!et Strvllllt MId OJ Deslg'n DIISIlD t(O,. 046Gn* Bultl 8pa;W)O._

fal(t) VOlb 1816 2a24108 .

A\iaticn and A!J1o "'1M Ii' I lll' 28247-5 T-3Y4 AWlJOl\ irxflnarc:iw . 8 at) .001 .-

.. .. ,,' .10 . -.. , ,,, ........ , tI -1m T-3'A lttd'Qtlr B

,05 18211 29267-3 r-sYi Cdn M.utll1e and Indic:a.lor 8 28.00 .. ,m 1. 2&278-3 IJllatOi' i 5Q.00 .05 '847 2BaM-8 'I'.a14 Radi O. TV MId IM<alOr s 6,SO .15 .. 1864 302 1 4-5. T-3Y.

a 28.00 ,'7 18&6 2.82'94-1 T-3Y. Raflo, 'IV M tl lnditJtor B 6.3D .2S Uti 2&30N T-3W ALlli) 9 14.00 ,27 1tl1 28304,J P.:uliD and IhI1k2lcr a . .24 GE Type ET-16 Bulb Spec: 28V, 0.04A, 1.12W GE Type ET-16 Socket Spec: 20000 Bulb Resistance

= (1.12W)/(0.04A)

= 700 0 Total Resistance

= 2000 0 + 700 0 = 27000 Current at 120V = (120V)/(2700

0) = 0,044A Burden = (O.044A)2 X 2700 n = 5.33W 10116102754692

.Ap.wl. Mun _d AV;. flalgn canUla Lift WllltJ {M$tlf) IHIlu=l 8iJ1t .. ....., ... /In. , ....... ,"' ". .... W*.N_Y_ 1.12 .l;1 4inl MI'I. eav. 2.&0 lotiO 1000 J.Gn.9w. 1.$8 .65 Min. hi. Uti 1,00 1000

.. Z1S 1.10. SOOO Jl5 .38 1S.000 Mln.&ay. 4.1& 3..<<1 1!1JO Min, Bay. loSS ,ts MlI\Ba1. 3,78 UlG 3500

$.36 2.10 filO tI.!'1I.&tJ.

Page 99 of 152 PAGE 4/ . Miniature Lamps Ugtd Nu. flLamolll C4111lt OVOF41U Dc;ja' lUGUt nallM 1II. mm In. IfIIII '!i.e 1711 ;,\ J .... 4* l' e-2\' Y1 1S.9 It\, 31 C;2f 1509 1'1<0 31 (}2f '5.9 n;, 3 1

'7i lS.i 11'ot 31 C*S '" 15,9 "i'\. 31 C-2R 16.0 HI. 31

  • 1$, 9 W.., 31 13r,; 18.0 31 142 HI! 3 1 01.. 4A ,.lJ <I)-c' I CALCULATION NUMBER: 9000041128 REVISION:

1; LEGACY NUMBER: 357S-DC ATTACHMENT "1" PT Burden Calculation Exhibit (8): Rochester Alarm Relay 1200L Burden ET*1200 AC Current/Voltage Alarms These single and dtJai trip alarms aceept a.c current or voltage inputs (fIeld aUerabte) and provide one DPDT 5 amp (ET*1200llU) or two SPDT 6 amp (ET-120WU) unIversal relay contact OU1puts. Basic Input spans of 16 to 200 Vac or 0-1 to 0-7.5 ,amps. All models come with flKed.deadband less than 0.5% oi span. Response time is less than 400 rniRiseoonds.

The ra.nge of al."ode1s is 50-500 Hz.

1200 at currentlVollage alarms conform to the IEEeSWC test Refer to the Options flection (pages 11*13) for a complete list of options for each model. . Available M,Pdels ET-120DLfU Ef..1202LfU OtseriD1fon Single trip eO CUrfenVvoltage afarm ' i Ou'a1 tripac Ctjtreollvdtage alarm Page 100 of 152 Input lSI Any BC current from 0.1 amp to G-7.5 ;:es ac, bUlden les§l than 0.5 VA 4If "aeV01tage-any Q..16 to 0-2Q() Vac signa burden less than 1.5 VA ") ; Input Frequency Range 5(l..SOOH%

Input Surge Be current-20 continuous; 250 amps for 1 second per hour ec votta9e--2OO%

of Input sPecified, oonfinuoqs

' Oeadband Rxed less than 0.5% ()f !ipan Oontrols 20 tum trip*set potentiomtner with Two 20 tum trip-sel pCttenliometers with dod<wlse rotation to Increase seltiM olool'\wise rotation to inorease setting Trip*Set Adjustment 0-100%

adjustment per trip-set point by i resolution potentiometer Trip Pomt Stability ana Drift :1::0.5% of span maximum lor a 50"F (28°0) change in amblen' temperature;

+/-O.2% tYpical LED-Visual indication One 1Wo of A1ann Condllfon Relay , II Hi Trip or Hilla Normally Energized ( . a1tsa::1e LoTnp LolHi Trip, or (NorrFaIl ) Hi/Hi Trip, or m Customer must select variable(s) and specify when orderIng, I CALCULATION NUMBER: 9000041128 REVISION:

1; LEGACY NUMBER: 357S-DC ATTACHMENT "1" PT Burden Calculation Exhibit (9): Westinghouse VAR & Wattmeter KP241 Burden Ac IM'h'umanU lm;a: Data. 60 Hertz Circular Scale K*2en Ac Ifi$trUmf1;Intl loss Data. 60 Cvcles. Circular Scale K .. 241 K*231. K-261 Burden on Current Transformers at 5.Amps Instrumant Tvpe ImP4l'oiJnoe:

and Aatin9 Ohm, Ohma Henries Ammetelll.

5 Spiral Vane KA .036 .02S .000066 Repu

@ KA .OHS .0'2 .000074 Raetlfler KC .002 .COUi and Varmecet#

KP\ .08 .016 .0002 (Per elgmillntp 5 Amp$ KVJ Factor Melets. KI .114 .14 'Amps KJ .045 .046 on Voltage Transformers at 120 Volts Tvpe hl1pcdam::tt:

Inductance:

ilnd Rating Ohms Ohm$ Henries VoHmeten:.

o-HiO VoUs: 120 Volts Spiral Vane KA. 8&40 8420 5.'1 Repulsion-Attr;)etlon

('j) KA 7530 1600 1.6 Roctifier ICC 19o,QOO lSO.000 Wattmeters Vannoter,.

120 .. Sjngle JKPt 9.000 9.000 Polyphase lKVl 18,000 18.000 Phue Shifter PS, 1 MV-S32' leAl 4,000 4.000 ... Volts Power F.actof 120 Veltt! Singh! Phil-3e KI KJ 12.000 12.000 Polypha$.lJ Kt KJ 14.000 14*;000 Svnc;tu:n$QI)p!)" 1 20 Running K. Incoming Volt-Ampares< .9 .315 .06 2.0 4.35 1.12 Volt-AmJ;lElt8s 1.79 1.92 .09$ 2.5 1.2:6 1.4 3.6 4.5 1.2 2.2 '"2 4.5 4.8 <D AU Hi-Shock typill!i and commeroiaf types prior 10 197' .m' DC 663 1 00-245 -6 PG583 POw.:." Factot .72 .80 .so .82 1,0 POWtlt ractOcf :98 .996 1.0 1.0 1.0 .36 1.0 ,45 1.0 1.0 1.0 .45 .SO Page 101 of 152 Ru-iltctive Voll-Arr!parltl .es .62.5 .30 .625 .04 .4 2.0 , 1.12 1.12 Walts Aeaeth,. Vall-Amperes 1.75 ,40 '1.92 .096 2.5 1.2.5 .5 L3 3,6 Z.O 4.1 1.2 2.2 1.2 2:.0 4.' 3.7 2.8 I CALCULATION NUMBER: 9000041128 REVISION:

1; LEGACY NUMBER: 357S-DC Page 102 of 152 ATTACHMENT "1" PT Burden Calculation Exhibit (10): Agastat ETR Time Delay Relay Burden Agasfatt&controJ relays TR series time delay .1 c./.JU'# I 71.r f?

I<w 11\ Operating voltage + 100141' -15% D.C. AC.* 24 VDC 120VSO-60Hz . 12SVDC Timing 3 Sec. 410120 Sec. .55 to 15 Sec. 10 10 300 Sec. 1 to 30 Sec. 2 to 60 Min. 2 to 60 Sec. 1 to 30 Min. Repeat Accuracy' Repeat accuracy at any fixed temperature is dafhied as: '*The repeat accuracy deviation (AFi) of a time*delay relay is a measure of the tianin lhe tim Helay lhat will be

  • experienced in 100 successive operations at any parncular time setting of the reray and for any particular operating voltage or current. . Repeat accuracy is obtai ned from the formula: A,., == 1 00 Whefe-T. == Maximum observed time. T: =' Minimum observed time. -NEMA part IGS

.07 Repeat Accuracy :.2% at fixed temperalure.

voltage, and of 1-time. Overall Accuracy!.

5% over bined !.'alad extremes of ture and voltage. Contacts Relay 4 POT "Oemps See GP serIes speclfications; "Conlacts.

,. Operating temperatu re range O"Cto50f>C Wiring Diagram A.C. and D.C. Timing Adjustment

'ntemal Fixed. 'nternat potentiometer.

Mounting/terminals 16 flat base pins which may be soldered.

Screw termInal or quick .. connect sockets Eire avail. able. life load life -.. see chart Mechanical life 1 DO. million load life characteristics CIJrlEI'Il II'! AMPS . ..IJj-2. J 2-S' P4-.

..:arr Transient Protection A 1500 von transient of less than 100 microseconds.

or 1000 volts of less than 1 millisecond will not feet timing accuracy

  • Insulation Resistance Between all non-conneCled riats as well as between connected terminals and the retay yOke: 1.000 megohms at 500 velts D.C. . '.J Power Consumption Typical power consumption at rated voltage Is: 6VA for A.C. colis, 6 Watts for D.C. coils. DlelectrJc 2000 VAC between terminals and case and between mutually.

isolated contacts.

Weight 11 0%, Net. ()

-Otil 125V US-V DC *o.e. -_....... tnlfuetl1lil'

-AeSi$flvl:

I CALCULATION NUMBER: 9000041128 REVISION:

1; LEGACY NUMBER: 357S-DC ATTACHMENT "1" PT Burden Calculation Exhibit (11): Potter & Brumfield KH Series Relay Burden POTTER & BRUMFIELD RELAYS Page 103 of 152 17 (J F 17

.... _.-_ .. _.-.. ---KHU . . . "-=-KH series';--;"'-" ...... -,GENERAL PURPOSE MUL TICONT AC,T AC or DC RELAY --tjU FUe'E22575

'C! File 'iU" File 29244 (Limited recognition of 5 pOle version.) ,GENERAL INFORMATION COIL DATA Only slighUj fargerthan a cubic inch. the KH Series At and DC Vo1taOt: From e to 120V DC, and 6 to 240V AC. 50/60 H%. """ ...... rilpresent an ,added dimension In switch-' Nom. PowM: DC coUs-O.9 watt; 0.5 watt minimum operate@ ....... ,. . ., 25*C. ing reliability.

These miniature re'ays are specifically designed to AO cotla-1.2 VA; o..ss VA mlnmwm .operata @ meet the euettng requirements of data photocopler.

25"0. , ptocess conirel and other applications.

Uu. POwer: 00' coits-2.0 witts @ 25*0. Design vanations.

including a va.tiety of case and termination

'Duty Cyelr. Continuous.

optl0n8. result in relays having different designators.

Several of mWalBreakdo'Wn V0ftag8: SOOV rms. 60 Hz. the veraions available are UL Reeognfzed and/or CSA Certified.

The Ilandard contacts are rated litO HP.3 ampe.120V AC; 3 OPERATE DATA amps, 30V DC. resistive.

Models with contacts rated to 5 amge DC: of nomlnal voltage @ 2S*C. are also availabte.

AC: 85% of nominal voltage @ 25 *C *. The kHS is hermeticaily sealed and UL apProved for Class 1. 0pendI nma: 13 mIlliseconds typical @ nominal voltage and DMsfcn'2 hazardous loCations. . +25*9 (exduding bounce). . For quick selection of features aYalJaDle

'foi KH serieS' refays.--

6-milliseconds typical @ nominal vottag& and-*-please refer to ItJe Ordering information table. + 25-0 (exctl.ldiJ'lg bounce). '--.', -". .

.. C.----ENGINEERING DATA CONTACT DATA . uaCHAHICA1DATA 21!!'-C(DPOT) AF .u:e ,.

  1. 3-48 stud, IiOCkets WIth printed circuit or BOlder ..........

'\II'MlnrJlwt:

rurm, ... orm "I ., enl,l .... orm OJ terminals.

or bracket .... wIth 1# 6-32 -reft"'-d

-(5POT) (KHS & KHU only). Other arrangements "'""" .. III -available on special ()tder.

Printed circuit. 80Ider 18O(:ket or taper tab tenn\-ftatiftgll!

See contact ratings table. nals. Printed cfreu!t terminals are available for KHS Ultetfa!:

See contact raUngs table, . on a special order basfs. Ln.: 10 million operations, meehanieat; 100.000 ope,... lnaulatln; Matl.iMb Molded higtHIlefectrfc material.

alions minimum at rated loads. Ratings are Eftcfo$UMt:

See Ordering lnfOnnatlon table. Cover colors 8,e baSed on tests of relays with ungrounded framea. available In black. ,ed. blue. yelloW and Dr"n by InitfatB _L""_ U . . . , apeciatorder. , rewa""".n yoltage: SOOV rms., eo Hz. between open con-,W.lght: 1.6 oz. approx. (45 gms..) t&ctI.1240V rms. 60 Hi. between aU other elements.

COIL DATA FOR KH SERIES CONTACT RATINGS .....

tIattftII IItnlaum M.llm .. , auv.r 100mA o 12VACIUVDC

$A

  • l2OVACiI28VDC Sitwt t-ca4tMum o.iIJt IOOmA
  • 12 ...... Ct12VDC SA. ,ZOVAClI28VDC

_I Goo1d-tiMr*lIicl!ef fOmA

  • 12VACI12VOC 2A 0 t2OVA.c.t2iVIJC
  • 1COmA
  • UVACt12VOe

-' SiIlNallor

.500mA.,2VAClt2VDC

$A 0 12OVAC/2!VDC

  • ""'ca"f CtaU bllr
  • 1A012OVACoI3OVOC

-. VOI4 twtI&y ,11m ., Gc40alfcy lOOP. 0 3V4C13VOC

...... ' 1A012OVACI28vtIC SOmA

  • 12V1!.Cl1.wtJC 12CVACI2IVDC only cany a maximum of 15 amps contin..,..

-'I HcmII'III Votlllle'

  • 12 ... .. 10 110
  • 12D. NO DeCOU ACCOU NcmtftaI HomIntI 0h8 :!: ftIMt
  • MOhIM ACCummt .," .. "'....."..
1::1$" en""" .. .os 1o.s --.. .0 --1.0 1110 12 I,D u .. Zii 1,0lI0 u.s --11.-V.D --u.soo -U!>> 11.0 --12.000 6.0 CALCULATION NUMBER: 9000041128 REVISION:

1; LEGACY NUMBER: 357S-DC ATTACHMENT "1" PT Burden Calculation VA Spec for AC Coil = 1.2 VA Wattage = (0.011)2 X 3900n = O.47W Page 104 of 152 I CALCULATION NUMBER: 9000041128 REVISION:

1; LEGACY NUMBER: 357S-0C ATTACHMENT "1" PT Burden Calculation Exhibit (1 2): Action Pak AP6380 Isolator Burden Specif ica t ions Input Ranges (se l e ctable) V oll age: 50mV AC 10. 20 0 V AC SmA AC 10 10CmA f lC Input Frequency DC-1KHz, fada rl cali l:fa led at 60 H z l"put Impedance Volt:!ge: >1OC q( O hms Cu rr ent 20 Ohm s typi ca l Input Overload (wi t hout damage) Voltage: 3'ODV AC Cu rr ent 20DmA AC , 60V peak Common Mode Voltage 1S0 0V DC, r , put to ground OUIJlut Rang es (selectable)

Vc!t oge: O-SV DC , O*10V DC C urrent: 4*20mA DC, 0*1 m ,<\ D C Output Source Impeda n ce V dtrl ge: ..;10 O hms Curren t >1 00 K Ohm s Mounting AIiA c li on Pa ks r ea t ure p l u g-in i ns tall a U o n. Mode l A P 6380 ll SCS an 6-pin bas e, e i ther molded socket (MOOB) o r DIN r a il socket (MD08), Ordering Information Specify: 1. M O del: AP 6 380-000 0. 2. Op lion U (see l e x t). 3. Line P owe r (see specs). 4. Optional F ac t o ry C a librallon (C620): Spoci fy inpu t range, o u tp u t ran ge and power. 5. COD6 (O.1 Oh m shun t fo r 1 to 5 Amp cur r ent in pu ts). Pin Connections 1 AC Po wer (H ot) 2 Shie l d (GND) 3 AC Powe r (Neu) 4 Spar o T e anination 5 Input 6 In pu t 7 Outp ut (+) 8 Output H rnvensys EUROTHERM Eurotherm Controls 741.-F Miller DrIve Leesburg, VA20175*B993 703-443-0000 info@eurotherm.com act/onia.com

  • Action Instruments
  • Output Drive V o l tage: lO m A. max (1K Oh ms min. @ 10V) OJrr dl t: 20VDC o:m#ia ll re (l K O h ms

@ 2OmA) Span Turn Down 50% o f f ull s cale ra n ge Ze r o Tum Up 00% of f uf l s ta!'e range LEO Indication 8H z fla s h when Inpu t is 10% above fu n s ca l e AcclR'acy (including hysteresis ami linearity)

I:Il.1% of s pa n, typica l +/-O.S% o f spa n, max imum Response Time 2S0 rnSec , . Stabi l ity +/-o.o25% of full scale p e r °c , Common Mode Rejettion 120dB , DC to 60l-ll Dimensions D ime ns i ons a r e i nm i i li m eters' (i nc hes) I solation (input to output to power) 1 500V DC or peak AC Tl)mperaluro Range Operati ng: 0 to 60'C (32 to 140'F) Slorag e: *15 t o 70'C {5 to Humidity (Non.C ondensing)

Power C ons umpt bn: 3W typ:tal, 5W max S tandard: Selectable 12 0 1241lV AC +/-HT%, 5I).OOHz)

Weight O.60 1 bs Agency Approvals CSA rerlified per stan dard C22.2, No. t.I 1982 (filE; No , lR42272'38). UL reoognlzed p ()r slanda r d UL50e (File No , E 150323), 11M G 9_1) __ ' ----t MOOS (Track/Surface)

Mooa (DIN Rail) factory As sistance Barber-Colman

  • For additional infonnation on calib rat io n, operation a nd installa t ion con tac t our Tec h nic a l S e rvic es Group: 703-669-1131 8 actionsupport@curotherm.com 72.1-048Z*OO-M 09/04 Copyright@)

Eurotllerm, Inc 2004 Eurotherm Chessell

  • Eurotherm Controls
  • Page 1 05 of 152 I I CALCULATION NUMBER: 9000041128 REVISION:

1; LEGACY NUMBER: 357S-DC Page 106 of 152 Exhibit (13): Potter & Brumfield MDR-4103 Burden ATTACHMENT "1" PT Burden Calculation

'"--, ___ .,---",7 \ Of.\ . .SIfIn I ...... .....,. CU""OME.* -A'JA"

..

AltlJF ' ... u.

.-.-_

' £'fi NO. ,

COIL VOLTAGe: 'I .... !o OPEAA"Tf

...

0.'1..

_l.£ASEVOi..'A'E; W-'WIi.. to ..... YIL

  • DC R'E'$ISTANtE Of' CoIL: CWlV4 I POWER (STEADY STAtl): r I HJtU$lt CURRENT
URltE=tIIT (5 T*MY SlA.TE::):

b.,\,-:A ,

TUE: ('!tAlI "Q \u:. "'ftti\to"-

I REt£A.i.E TlHE: .4!S.!." ...... ;, .. u.--.", . CONTACT. MTINc;S ,! . S.

COftTAC1S . -0 VAt:. 50"" '"' !It AMPS 1., V&)oC IRE:$1 S T I VE oA N1PS \,.'-vtX 'RES r STIVE . TW"3 COftT ACTS IN SE UcS f NII#IS '111i\t..

1!A"!4;'" , .... N'W'S w*. vAt: 50 \I.,." N'lPS\",,, VDe RESlST'I VE RN-tG£:

-,; .... \':1 C(:HYAtT SE(:TI0NS TOTAL) .... A:1"./', lit of... '"

'-'" J \/jJJ. = '120\( X O.1 S.A. = 1 B\'A 1,,\" = .4. D '",\,f . ....,. .... "l1li. ....... RPE..E 'Lf p t;p K .MC___

.,. ' J ot...!'t--

HOTE: .... -. -----__ t !!-l.EC .. R [CAt. YAl.UES .1 YEN. II\!O.VI! HEASURE.D AT '. N. PRCX.I ....

25 OfGA.E£S C ..

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